Horizon Power - Low Voltage EG Connection …...(EG) connections information about their obligations...

Low Voltage EG Connection Technical Requirements

Standard Number: HPC-9DJ-13-0002-2019

CS10# 11786486 Standard HPC-9DJ-13-0002-2019 of 107 Print Date 11/10/2019

© Horizon Power Corporation

Uncontrolled document when downloaded. Refer to CS10 for current version.

Document Control

Author

Name: Wilbur Wong 30/05/2019 Position: Planning Manager

Reviewed by

Name: David Stephens 31/05/2019 Position: A/Manager Capacity

Management Support

Document Owner

Name: David Stephens 31/05/2019 Position: A/Manager Capacity

Management Support

Approved By Name: Brett Hovingh 7/06/2019 Position: A/General Manager

Power Systems

Date Created/Last Updated 7/06/2019

Review Frequency 2 years

Next Review Date May 2021

Revision Control

Revision Date Description

1 7/06/2019 Initial document incorporating ENA National Connection Guidelines. This document supersedes standard HPC-9FJ-12-0001-2012.

1.1 25/06/2019 Minor update to include Schedule 5 System Parameters

1.2 11/10/2019 Minor update to Appendix F – Summary of Inverter Settings

STAKEHOLDERS The following positions shall be consulted if an update or review is required:

Manager Pilbara Manager Goldfields Esperance

Manager Midwest Manager Generation

Manager Kimberley Manager System Operations

Manager Consumer Energy Manager Customer Service

Engineering Services Manager




CONTENTS

1 Introduction ...................................................................................................... 8

1.1 Scope – Inclusions ................................................................................................. 8

1.2 Scope – Exclusions ................................................................................................ 9

1.3 Proponent Responsibilities ..................................................................................... 9

1.4 Horizon Power Obligations ................................................................................... 10

1.5 Hosting Capacity .................................................................................................. 10

1.6 Existing Low Voltage EG Connections .................................................................. 11

2 Definitions and Abbreviations ...................................................................... 12

2.1 Definitions ............................................................................................................. 12

2.2 Abbreviations ........................................................................................................ 18

2.3 Terminology .......................................................................................................... 19

3 Relevant Rules, Regulations, Standards and Codes .................................. 22

3.1 Standards and Codes ........................................................................................... 22

3.2 Legislation and Regulation ................................................................................... 23

3.3 Order of Precedence ............................................................................................ 23

3.4 Useful Links .......................................................................................................... 24

4 Technical Requirements ............................................................................... 24

4.1 Labelling and Signage .......................................................................................... 25

4.2 Maximum System Capacity .................................................................................. 25

4.3 Generation Control ............................................................................................... 25

4.4 Inverter Energy System ........................................................................................ 31

4.5 Network Connection and Isolation ........................................................................ 32

4.6 Earthing ................................................................................................................ 32

4.7 Protection ............................................................................................................. 32

4.8 Operating Voltage and Frequency ........................................................................ 36

4.9 Metering ............................................................................................................... 36

4.10 Power Quality ....................................................................................................... 37

4.11 Communications Systems .................................................................................... 43

4.12 Data and Information ............................................................................................ 50

4.13 Cybersecurity ....................................................................................................... 52

4.14 Technical Studies ................................................................................................. 52

4.15 Systems with Energy Storage ............................................................................... 53




5 Fees and Charges .......................................................................................... 55

6 Testing and Commissioning ......................................................................... 56

6.1 Type Testing of Renewable Energy Smoothing Systems ...................................... 57

6.2 Routine Testing of Renewable Energy Smoothing Systems ................................. 57

6.3 Testing and Commissioning of Communications Systems .................................... 60

6.4 LV EG System Commissioning ............................................................................. 62

7 Operations and Maintenance ........................................................................ 63

7.1 Compliance Audits ................................................................................................ 63

Appendix A. Deviations from the National DER Connection Guidelines .......... 64

Appendix B. Connection Arrangement Requirements ........................................ 65

Appendix C. Model Standing Offer (Connection Agreement) ............................ 68

Appendix D. Static Data and Information ............................................................. 69

Appendix E. List of amendments to previous version ........................................ 70

Appendix F. Summary of Inverter Settings .......................................................... 71

Appendix G. Example of Ramp Tests ................................................................... 75

G1. Example Ramp Down Test ............................................................................ 75

G2. Example Ramp up Test ................................................................................. 76

Appendix H. Horizon Power Service Area ............................................................ 78

Appendix I. System Impact Study Model Requirements ..................................... 79

Appendix J. Pre-commissioning Data .................................................................. 83

Appendix K. Post commissioning data ................................................................ 84

Appendix L. HORIZON POWER’S SCADA INTERFACE ...................................... 85

Appendix M. COMMUNICATIONS GATEWAYS .................................................... 87

Appendix N. REQUIRED MODBUS PARAMETERS .............................................. 90

Appendix O. ON SITE NEXTG CELLULAR SIGNAL STRENGTH CHECKLIST ... 92

Appendix P. LV EG CONTROL SYSTEM INFORMATION SHEET ....................... 93

Appendix Q. COMMUNICATIONS SYSTEMS – Schedule of Tests ..................... 95




Schedule 1. Proponent Compliance Checklist .................................................... 98

Schedule 2. System Diagram .............................................................................. 100

Schedule 3. Circuit Diagram ................................................................................ 101

Schedule 4. Cable Data ........................................................................................ 103

Schedule 5. System Parameters ......................................................................... 105

Schedule 6. NER Signoff ..................................................................................... 106




Tables Table 1: Connection Types .................................................................................................. 8

Table 2: Definitions ............................................................................................................ 12

Table 3: Reference Documentation – Standards and Codes .............................................. 22

Table 4: Reference Documentation – Legislation and Regulation ...................................... 23

Table 5: Order of Precedence (Highest to Lowest) ............................................................. 23

Table 6: Useful Links.......................................................................................................... 24

Table 7: Summary of Technical Requirements ................................................................... 24

Table 8: Passive Anti-Islanding Settings ............................................................................ 33

Table 9: Central Protection Requirements .......................................................................... 33

Table 10: Central Voltage and Frequency Protection Set Points ........................................ 35

Table 11: Volt-Watt Response Reference and Maximum Set-Point Values ........................ 38

Table 12: Volt-VAr Response Reference and Set-Point Values ......................................... 40

Table 13: Communications Functional Requirements ........................................................ 44

Table 14: Monitoring Requirements ................................................................................... 45

Table 15: Communications System Performance Requirements ........................................ 50

Table 16: Technical Studies Required for LV EG Connections ........................................... 53

Table 17: Horizon Power Fees and Charges for LV EG Connections ................................. 55

Table 18: Testing and Commissioning Requirements for LV EG Connection ..................... 56

Table 19: Types of Test Methods ....................................................................................... 57

Table 20: Test Points ......................................................................................................... 59

Table 21: Action Required Once Test Result Obtained ...................................................... 60

Table 22: Table of Deviations from National DER Connection Guidelines .......................... 64

Table 23: Summary of Required Inverter Settings .............................................................. 71

Table 24: Example Ramp Down Test Parameters .............................................................. 75

Table 25: Example Ramp Down Test Data ........................................................................ 75

Table 26: Example Ramp Up Test Parameters .................................................................. 76

Table 27: Example Ramp Up Test Data ............................................................................. 77




Figures Figure 1: Ramp Down Rate with and without Renewable Energy Smoothing ..................... 28

Figure 2: Ramp Down Characteristic Curve ....................................................................... 29

Figure 3: Volt-Watt response curve .................................................................................... 38

Figure 4: Power factor operational requirements for normal operation ............................... 39

Figure 5: Volt-VAr response curve ...................................................................................... 40

Figure 6: Over frequency response (Indicative) ................................................................... 41

Figure 7: Under frequency response (Indicative) ................................................................. 42

Figure 8: Example of Ramp Down Test Measurements Where Result is TEST FAIL ......... 58

Figure 9: System Diagram D - Generation Managed with Communications and Smoothing ........................................................................................................................................... 66

Figure 10: System Diagram E – LV EG connection with Communications ......................... 67

Figure 11: Example Ramp Down Test Results ................................................................... 76

Figure 12: Example Ramp Up Test Results ....................................................................... 77

Figure 13: Horizon Power Service Area map showing NWIS ............................................. 78




1 INTRODUCTION The purpose of this document is to provide Proponents of low voltage embedded generation (EG) connections information about their obligations for connection to and interfacing with Horizon Power’s low voltage (LV) distribution network. This includes all customer connected EG, regardless of whether such systems export electricity into the electricity system or not.

1.1 Scope – Inclusions The Electricity Networks Australia (ENA) framework and principles guideline outlines five categories of embedded generation connection, as outlined in Table 1. This technical requirements document applies to new connections of low voltage EG systems or modifications to existing low voltage EG systems, where the low voltage EG system consists of inverter energy system (IES), energy storage system (ESS) or a combination of both.

Table 1: Connection Types

Connection Type

Connection Voltage

Technology Type

Capacity Relevant Standard

Basic micro EG connection

Up to 1kV Micro EG (inverter based)

≤30kVA three phase,

≤10kVA single phase

Basic Micro EG connection Technical Requirements

Low voltage EG connection

Up to 1kV Inverter Based

>30kVA and ≤1MVA three phase

Low Voltage EG Connection Technical Requirements

(This Document) Non- inverter based

>30kVA and ≤1MVA three phase ≤10kVA single phase

Medium voltage connection

1kV to 35kV Any Any size up to 10MW

Horizon Power Technical Rules

High voltage connection

>35kV Any Any size up to 10MW

Horizon Power Technical Rules

Registered generator connection

>35kV Any >10MW Horizon Power Technical Rules

A low voltage EG connection, consistent with the definition provided within the ENA Framework and Principles guideline is:




A low voltage EG system with a total system capacity of greater than 30 kVA and less than or equal to 1000 kVA for a three-phase IES (excluding ESS1) network connection, that is:

a) intended to be connected to and capable of operating in parallel with any part of the LV distribution network

b) meeting all other technical requirements set out in this document OR A LV EG system with a total system capacity of greater than 0 kVA and less than or equal to 1000 kVA for a single-phase or three-phase non-IES (synchronous or asynchronous) network connection, that is:

a) intended to be connected to and capable of operating in parallel with any part of the LV distribution network

b) meeting all other technical requirements set out in this document This Document is applicable to all types of EG connected to Horizon Power’s LV distribution network, including renewable energy sources such as solar PV, wind and mini hydro. The Proponent’s connection application shall identify each type of renewable energy source per connection. This Document is applicable to single phase and three phase supply arrangements. For key criteria of single and three phase connections, refer to the Western Australian Electrical Requirements (WAER) and Western Australian Distribution Connections Manual (WADCM).

1.2 Scope – Exclusions The technical requirements do NOT apply to the following system types:

a) EG units covered by Horizon Power’s Basic Micro EG Connection Technical Requirements

b) EG units covered by the technical requirements for medium or high voltage (MV/HV) connected EG’s

c) Electric vehicles, unless the on-board battery storage system is capable of exporting to the LV network (in which case the requirements shall apply)

d) Distributed Energy Resources (DER) systems that do not generate electricity, including demand response/demand management systems, unless they impact on the ability of the low voltage EG system to meet the technical requirements

e) Off-grid systems such as Standalone Power Systems (SPS).

1.3 Proponent Responsibilities The Proponent shall comply with all the applicable requirements of this document. The general obligations of Proponents include:

a) The obligation to comply with the technical requirements as well as relevant national standards, industry codes, legislation and regulations. In the event of inconsistency, an

1 Note that ESS are permitted within LV EG connections. However the ESS capacity is not included in the total system capacity definition of the LV EG connection.




indication of which instrument shall prevail, being legislation and regulations, followed by the technical requirements, followed by national standards and industry codes

b) The obligation to not connect additional inverters, make modifications or install additional EG units, including ESS, without prior written agreement from Horizon Power

c) The obligation to comply with Horizon Power’s model standing offer d) The obligation to meet the requirements in the design, installation and operation of the

low voltage EG system e) The obligation to meet the connection and commissioning requirements to the LV

distribution network f) The obligation to procure equipment and to arrange for its installation in compliance with

these technical requirements as well as all other applicable Australian Standards and Regulations.

g) All design and installation works for LV EG connections with renewable energy sources shall be undertaken by a Clean Energy Council (CEC) accredited persons, with certification appropriate to installation type.

Horizon Power may, at its absolute discretion and without limiting any of its other rights, reject an application or disconnect the LV EG system from the grid if the Proponent’s LV EG system does not comply, or, no longer complies with all the requirements of this Document through modification being made to the Proponent’s LV EG system. Should the Proponent’s total LV EG connection capacity exceed that of existing supply arrangement, then the additional electrical capacity requirement may call for the network to be modified to facilitate the LV EG connection. The costs associated with providing that additional capacity would be charged to the Proponent. The Proponent may choose to retract or modify their presented DER connection application. It would be treated as a new DER connection application by the Proponent and associated fees and charges shall apply. The size of the LV EG system may necessitate upgrading of the Proponent’s connection.

1.4 Horizon Power Obligations Horizon Power acknowledges its obligations to ensure the safe and reliable operation of the distribution system for operating personnel, customers and the general public. The technical requirements comply with the National DER Connection Guidelines for Low voltage EG connections, with the exception of the deviations presented in Appendix A: Deviations from the National DER Connection Guidelines.

1.5 Hosting Capacity Horizon Power presently allows connection of a fixed total amount of customer EG capacity to its electricity system. This amount of embedded generation is known as the Hosting Capacity and varies from town to town as it is set at a level that allows Horizon Power to technically and contractually deliver safe and reliable electricity. Refer to Horizon Power’s website for nominated Hosting Capacity for each of its systems and the available capacity. Where Hosting Capacity has been exhausted at a particular town, the Proponent can choose to apply to install an Extended Ramp Rate Smoothing system, which may be considered by Horizon Power. Refer to Section 4.3.5.




1.6 Existing Low Voltage EG Connections All existing low voltage EG connections already approved to connect to Horizon Power’s systems shall comply with the version of the Technical Requirements at the time of their connection. Where Proponents modify or upgrade their existing system, their existing low voltage EG system will be required to comply with the low voltage EG Connection Technical Requirements and meet their obligations outlined in Section 1.3, and they are required to submit an application to Horizon Power. Where a new system is added to a Premises with an existing approved EG system, the existing EG system does not need to meet the latest Technical Requirements however the new system must fully comply with the requirements set out in this Document.




2 DEFINITIONS AND ABBREVIATIONS

2.1 Definitions This section provides a list of definitions for technical or industry terms used throughout this document. In addition to those terms listed in the relevant Australian Standards (including AS/NZS 3000 and AS/NZS 4777), WAER and Electrical Licensing Regulation E(L)R, the following definitions apply:

Table 2: Definitions

Term Definition

Basic micro embedded generation connection

A connection between a distribution network and a retail customer’s premises for a micro embedded generating unit, for which a model standing offer is in place or an equivalent model offer is in place in jurisdictions not subject to Chapter 5A of the National Electricity Rules

Battery Energy Storage System

A device used to store energy in the form of chemical energy.

Break before make switch A switch that opens a connection prior to closing the new connection.

Central protection Central protection is the protection contemplated by AS/NZS 4777 (grid connection of energy systems via inverters) installed to perform the functions of: coordinating multiple inverter energy system installations at one site, providing protection for the entire inverter energy system installation and islanding protection to the connected grid as well as preserving safety of grid personnel and the general public

Completion Notice An electrical contractor, who carries a notifiable work, shall provide notice of completion within the period of 3 days after its completion. Refer to Electricity (Licensing) Regulations 1991 for details.

Connection Point That point defined in an access contract or, where there is no specific access contract, the upstream terminals of the customer’s main switch or downstream of the meter.

Current Transformer A current transformer is used for measurement of alternating electric currents.

Customer Final Loads All electrical loads on the Customer’s premises not part of the Renewable Energy Installation




Term Definition

Distributed Energy Resources

Power generation or storage units that are connected directly to the distribution network

A general description for the range of distributed energy devices such as dispersed power generation (including solar PV), energy storage, demand management and smart inverters located at customer premises or connected directly to the distribution network.

Whilst DER is often used to refer to renewable generation sources, it also includes dispersed non-renewable generation sources.

Distributed Energy Resources Management System

This is Horizon Power’s control system for managing distributed energy resources.

Document This document and any annexed schedules, together with any document referred to, or incorporated into, this document.

Electrical Installation As defined in AS/NZS 3000

Electricity System The electricity grid owned and operated by Horizon Power and connected to the Premises.

Embedded generating system

A system comprising of multiple embedded generating units

Embedded generating unit A generating unit connected within a distribution network and not having direct access to the transmission network

Energy Storage Device A generic device that stores energy in the form of electrical, mechanical or chemical energy.

Energy storage system A system comprising one or more batteries that store electricity generated by distributed energy resources or directly from the grid, and that can discharge the electricity to loads

ESS Capacity The energy storage system capacity (kVA)

Note ESS Capacity does not refer to the energy capacity (i.e. kWh) it refers to the IES capacity directly associated to the ESS (kVA)

Extended Ramp Rate Smoothing

A type of Renewable Energy Smoothing requirement to facilitate DER connections in towns where Hosting Capacities are reached. It is subject to case by case assessment by Horizon Power.

Feed-In Management A type of Generation Control, where the EG output is curtailed to prevent system instability.

Generating unit The plant used in the production of electricity and all related equipment essential to its functioning as a single entity.

Generation The production of electrical power by converting another form of energy in a generating unit




Term Definition

Generation Control Includes the utilisation of technologies such as inverter control, energy storage or feed-in management to control the output profile of the embedded generator.

Generator A person who owns, operates or controls a generating unit

Grid Shall have the same meaning as defined in AS/NZS 4777.

Hosting Capacity The capacity of the Electricity System to accept or manage the output of Renewable Source Electricity from a Customer’s System whether because of a technical limitation, insufficient reserve generating capacity or contractual constraint.

Inverter The device forming part of a System which:

a) limits the Renewable Source Electricity exported to the Electricity System;

b) complies with the Technical Requirements;

c) may convert direct current generated electrical energy into alternating current electrical energy; and

d) relates to the AS/NZS 4777 definition.

Inverter energy system A system comprising one or more inverters that convert direct current to alternating current

IES Capacity The inverter energy system nameplate rating (kVA)

Low voltage The mains voltages as most commonly used in any given network by domestic and light industrial and commercial consumers (typically 240V)

Market generating unit A generating unit whose generation is not purchased in its entirety by a retailer (and receives payment for generation through the National Electricity Market or Wholesale Electricity Market)

Medium voltage/ High voltage

Any voltage greater than 1kVAC

Metering Equipment As applicable, the import, export, bi-directional, parallel and revenue meters installed at the Premises to measure the import and export of electricity to the Installation under the Electricity Supply Agreement and the Renewable Electricity Exported by the Customer.

Micro embedded generation connection

Means a connection between an embedded generating unit and a distribution network of the kind contemplated by Australian Standard AS/NZS 4777 (Grid connection of energy systems via inverters) currently up to 200kVA

Mini Hydro A renewable generation source less than 1MW that creates electrical energy as a result of harnessing moving water.




Term Definition

Model standing offer A document approved by the Australian Energy Regulator as a model standing offer to provide low voltage embedded generation connection services or standard connection services which contains (amongst other things) the safety and technical requirements to be complied with by the proponent. This definition also applies to an equivalent model offer for jurisdictions not subject to Chapter 5A of the National Electricity Rules.

For Horizon Power this refers to the contractual agreement between Horizon Power and the Proponent for the connection of the EG system.

Multiple–mode inverter An inverter that operates in more than one mode; for example, having grid-interactive functionality when mains voltage is present, and stand-alone functionality when disconnected from mains supply. A stand-alone inverter that can inject energy into the grid would be considered a multiple-mode inverter.

Point of Connection Same as Connection Point

Off-grid system A property which does not have Horizon Power’s tariff meter on their premises and / or is not connected to Horizon Power’s distribution network; this document is not applicable to off-grid systems.

Power Conversion Equipment

An electrical device that converts one kind of electrical power from a voltage or current source into another kind of electrical power with respect to voltage, current and frequency. This category is for devices which are not inverters, but are connected between a renewable energy generator and an application circuit. Examples include DC/DC converters and charge controllers.

Shall have the same meaning as defined in AS/NZS 4777

Preliminary Notice The preliminary notice for notifiable works shall be provided as per the Electricity (Licensing) Regulations 1991.

Premises The premises nominated in the Application Documents, owned or occupied by the Customer, which must be the same Customer supplied at that premises in accordance with an Electricity Supply Agreement.

Proponent A person proposing to become a generator (the relevant owner, operator or controller of the generating unit (or their agent))

Prosumer A Horizon Power customer that installs a renewable energy system to offset their energy consumption.

Photo Voltaic A renewable energy generation device that creates electrical energy as a result of harnessing energy from the sun collected on photovoltaic cells.




Term Definition

Registered generator A person who owns, operates or controls a generating unit that is connected to, or who otherwise supplies electricity to, a transmission or distribution system and who is registered by the Australian Energy Market Operator as a Generator under Chapter 2 of the National Electricity Rules.

For Horizon Power this means a generator greater than 10 MW.

Renewable Energy Installation Control System

Devices that perform control and monitoring of the Renewable Energy System Installation.

Renewable Energy Producer An entity whose primary purpose is to generate and sell renewable source electricity to Horizon Power.

Renewable Energy Smoothing

Participating customers to install Renewable Energy Smoothing Devices that mitigate system instability risks. For example; energy storage, load control or any other method that meets the required ramp rates.

Renewable Energy System a) a system of photovoltaic arrays;

b) a system of wind turbines;

c) a hydropower system; or

another system for the generation of electricity from a renewable energy source, that has a generating capacity exceeding 1.5 kW but not exceeding 1 MW unless otherwise agreed in writing by Horizon Power.

Renewable Energy System Installation Size

The nominal output rating in kW of the grid connected inverter.

Renewable Source Electricity

Electricity generated by a Renewable System.

Secure Gateway Device This is the control interface between the Proponent’s EG system and Horizon Power’s communications system. This device is for the purposes of feed-in management control of the EG system.

Single Wire Earth Return Parts of the electrical distribution network that use a single live conductor to supply single-phase or split-phase electric power with higher network impedances, and with distribution supplying low voltages to premises

System Capacity The total installed nameplate rating (kVA)

System Impact Study A system study to assess the impact of renewable energy connection on Horizon Power’s generation and transmission & distribution network.

Site generation limit The generation threshold that the embedded generation system cannot exceed, measured downstream of the connection point




Term Definition

Small generation aggregator A person who has classified one or more small generating units as a market generating unit

Small registered generator A generator who elects to register a generator with the Australian Energy Market Operator as a market generating unit who would otherwise be entitled to an exemption to register based on size

Solar Thermal A renewable energy generation device that creates electrical energy as a result of harnessing the suns energy focussed on thermal collectors.

Spinning Reserve The amount of standby generation synchronised to the grid and available for immediate use.

Stand-alone inverter An inverter that is not designed to inject power into the grid, and is used for the supply of extra-low (ELV) and/or low voltage (LV) electric power to a single load, or an electrical installation via batteries or a renewable resource, PV, wind, hydro etc. The inverter may or may not contain a charging function.

Standard connection A connection service (other than a low voltage embedded generation connection service) for a particular class (or sub-class) of connection applicant and for which an Australian Energy Regulator approved model standing offer is in place or for which an equivalent model offer is in place in jurisdictions not subject to Chapter 5A of the National Electricity Rules

SunSpec Protocol A protocol facilitating the interoperability of distributed energy resources

System Diagram A conceptual diagram that illustrates the relationships between separate subsystems using lines.

System Instability A disturbance to the Electricity System that affects the reliability and quality of power to customers.

Technical Requirements This refers to the provisions set out in this Document.

These requirements may be in addition to the Horizon Power Technical Rules HPC-9DJ-01-0001-2012

Technical requirements document

The document produced by each Distribution Network Proponent setting out their requirements for proponents to enable a grid connection, to which these guidelines apply

Wind A renewable energy generation device that creates electrical energy as a result of harnessing moving air.

Zero Export Response Time Is the time spanning from the renewable energy export event detection to its effective reduction to a net zero export situation.




2.2 Abbreviations This section shall provide a tabulated list of all abbreviations used throughout the technical requirements document. The abbreviations shall be consistent with the abbreviations provided within the National DER Connections Guidelines (including these technical guidelines and the Framework and Principles guideline) as relevant.

Term Definition

AEMC Australian Energy Market Commission

AEMO Australian Energy Market Operator

AER Australian Energy Regulator

AS/NZS A jointly developed Australian and New Zealand Standard

BESS Battery Energy Storage System

CBD Central Business District

CEC Clean Energy Council

CT Current Transformer

DER Distributed Energy Resources

DERMS Distributed Energy Resources Management System

DNP3 Communication protocol. Distribution Network Protocol

DNSP Distribution Network Proponent

DRM Demand Response Mode

EG Embedded Generation or Embedded Generating

ENA Energy Networks Australia

ESS Energy Storage System

FiM Feed-In Management

GM Generation Management

HV High Voltage

IEC International Electrotechnical Commission

IES Inverter Energy System

LV Low Voltage




Term Definition

MEN Multiple Earthed Neutral

MV Medium Voltage

NEM National Electricity Market

NER National Engineering Register

NER National Electricity Rules

NIA Network Impact Assessment

NMI National Metering Identifier

NWIS North West Interconnected System

PCE Power Conversion Equipment

PLC Programmable Logic Controller

PV Photo Voltaic

REBS Renewable Energy Buyback Scheme

SCADA Supervisory Control and Data Acquisition

SGD Secure Gateway Device

SIS System Impact Study

SWER Single Wire Earth Return

SWIS South West Interconnected System

TCP/IP Transmission Control Protocol/Internet Protocol

WAER Western Australian Electrical Requirements

WADCM Western Australian Distribution Connections Manual

WEM Wholesale Electricity Market servicing the SWIS

2.3 Terminology The following instructional terms are to be interpreted as follows:

1. The word ‘shall’ indicates a mandatory requirement 2. The word ‘may’ indicates a requirement that may be mandatorily imposed on the

Proponent




3. The word ‘should’ indicates a recommendation that will not be mandatorily imposed on the Proponent.

2.3.1 Subcategories The following subcategories apply for low voltage EG connections, for which different technical settings may apply:

1. LV EG IES (excluding ESS) connection ≤200 kVA – Any LV EG system, that is not a basic micro EG system, with a total system capacity less than or equal to 200 kVA for a three phase IES (excluding ESS) network connection, meeting all relevant technical requirements for LV EG connections set out in this Document. Further subcategorised by:

a) Exporting b) Non-exporting

2. LV EG IES (excluding ESS) connection >200 kVA – Any LV EG system, with a total system capacity greater than 200 kVA and less than or equal to 1000 kVA for a three-phase IES (excluding ESS) network connection, meeting all relevant technical requirements for LV EG connections set out in this Document. Further subcategorised by:

a) Exporting b) Non-exporting

3. LV EG non-IES connection – Any LV EG system, that is synchronous or asynchronous, with a total system capacity less than or equal to 1000 kVA for a three-phase network connection or up to 10 kVA for single-phase, meeting all relevant technical requirements for LV EG connections set out in this Document. Further subcategorised by:

a) Exporting b) Non-exporting.

4. Non-standard network areas – LV EG connections shall be initially classified as either (1), (2) or (3), plus additional requirements apply to any low voltage EG system connecting to a non-standard part of the network including (but not limited to) SWER networks, isolated networks, and CBD networks.

Where: 1. Exporting systems shall be considered to be LV EG systems operating in parallel with

the LV distribution network and exporting electricity either via partial-export or full-export into the LV distribution network, where:

a) Partial-export LV EG systems limit the amount of export into the LV distribution network to an agreed export threshold defined in the connection agreement

b) Full-export LV EG systems can export into the LV distribution network to the full LV EG nameplate capacity (full AC rating).

2. Non-exporting systems shall be considered to be LV EG systems operating in parallel with the LV distribution network that are not approved to and limited to ensure they cannot export electricity into the LV distribution network.

The Technical Requirements apply to all of the above subcategories of basic micro EG connections. Each of these subcategories has differing technical settings and requirements.




Horizon Power currently identifies the NWIS as a standard network and all non-NWIS systems as non-standard networks in the application of this guideline. Refer to Horizon Power’s service area map in Appendix H. For all enquiries please contact [email protected].

http://dm.horizonpower.com.au/contentserverdav/nodes/11844255/mailto_Renewables%40Horizonpower.com.au




3 RELEVANT RULES, REGULATIONS, STANDARDS AND CODES

Unless otherwise stated within this Document, the Proponent shall comply with the current versions of all relevant legislation, technical requirements, Australian Standards, and applicable industry guidelines, whether explicitly identified or not, in Section 3.

3.1 Standards and Codes This section lists of all the Australian and International standards and industry codes which shall apply to the design, manufacture, installation, testing and commissioning, and operation and maintenance of all plant and equipment for low voltage EG connections to the distribution network. In the event of any inconsistency between Australian and International standards and industry codes and Horizon Power’s technical requirements, the Horizon Power technical requirements shall prevail.

Table 3: Reference Documentation – Standards and Codes

Horizon Power and Other Documents

WA Distribution Connections Manual (WADCM)

HPC-9DJ-01-0001-2012 Horizon Power Technical Rules

HPC-9OJ-13-0001-2012 Technical Requirements for Bumpless Transfer of Customer Load between Embedded Generators and the Distribution Network

Australian Standards

AS/NZS 3000 Electrical Installations (Wiring Rules)

AS/NZS 3011 Electrical Installations – Secondary batteries installed in buildings

AS/NZS 3017 Electrical installations — Verification guidelines

AS/NZS 3100 Approval and Test Specification – General Requirements for Electrical Equipment

AS/NZS 4777 (all parts) Grid Connection of Energy Systems via Inverters

AS/NZS 5033 Installation and Safety Requirements for Photovoltaic Arrays

Guideline Battery Energy Storage Systems: A guide for Electrical Contractor

DR AS/NZS 5139 (Draft) Electrical Installations – Safety of Battery Systems for use with Power Conversion Equipment

AS IEC 62619:2017 Safety Requirements for lithium cells and batteries

https://www.commerce.wa.gov.au/sites/default/files/atoms/files/bess_guideline.pdf

https://www.commerce.wa.gov.au/sites/default/files/atoms/files/bess_guideline.pdf




IEC 62109 (all parts) Safety of Power Converters for use in Photovoltaic Power Systems

IEC 62116 Utility-Interconnected Photovoltaic Inverters – Test Procedure of Islanding Prevention Measures

Codes

WA Electricity Industry (Code of Conduct) Regulations 2005

WA Electricity Industry (Metering) Code 2012

3.2 Legislation and Regulation This section provides a list of all the relevant legislation and regulations which shall apply to the design, manufacture, installation, testing and commissioning, and operations and maintenance of all plant and equipment for low voltage EG connections. In the event of any inconsistency between legislation and regulations and the Horizon Power technical requirements, the legislation and regulation shall prevail.

Table 4: Reference Documentation – Legislation and Regulation

Legislation

WA Electricity Licensing Regulation 1991

WA Electricity Act 1945

WA Electrical Requirements (WAER)

3.3 Order of Precedence In the event of a conflict arising between the reference documents listed in Table 4, the following order of precedence shall apply:

Table 5: Order of Precedence (Highest to Lowest)

Order Reference Document

1 Legislation

2 Technical Requirements

3 Australian Standards

The Proponent shall notify Horizon Power of any such conflict prior to undertaking work in relation to this document.




3.4 Useful Links Table 6: Useful Links

Name Link

Clean Energy Council http://www.cleanenergycouncil.org.au

Horizon Power http://www.horizonpower.com.au

Clean Energy Council Approved Inverters http://www.solaraccreditation.com.au

State Law Publisher (SLP) https://www.slp.wa.gov.au/Index.html

4 TECHNICAL REQUIREMENTS This section outlines the technical requirements and system diagram to be used for different subcategories of low voltage EG connections. The following table summarises the key technical requirements and considerations for different subcategories of low voltage EG connections:

Table 7: Summary of Technical Requirements

LV EG Connection Subcategory

Hosting Capacity

Required?

Feed in Management

Required?

Renewable Smoothing Required?

System Diagram

Horizon Power Assessments

Network Impact

Assessment

System Impact Study

Standard Network Areas

LV EG IES ≤200kVA

Y N N Diagram E

Y Y

LV EG IES >200kVA

Y Y N Diagram E

Y Y

LV EG non IES

Y Y N Diagram E

Y Y

Non Standard Network Areas

LV EG IES ≤200kVA

Y Y Y Diagram D

Y Y

LV EG IES >200kVA

Y Y Y Diagram D

Y Y

LV EG non IES

Y Y Y Diagram D

Y Y

Notes:

http://www.cleanenergycouncil.org.au/

http://www.horizonpower.com.au/

https://www.solaraccreditation.com.au/products/inverters/approved-inverters.html

https://www.slp.wa.gov.au/Index.html




1 A low voltage EG system is defined in Section 1.1. 2 Available Hosting Capacity: The Proponent is required to check if sufficient hosting

capacity is available for the EG connection in accordance with Section 1.5. 3 Feed in Management is mandatory for all low voltage EG connections >200kVA, and

all low voltage EG connections in non-standard network areas: Refer Section 4.3.6. 4 Renewable energy smoothing is required for all low voltage EG connections in non-

standard network areas. 5 System Diagrams: Refer to Appendix B for applicable system diagrams and

connection arrangement for each subcategory of system.

4.1 Labelling and Signage Labels and signs on the installation, including cables, shall be as per AS/NZS 4777.1, AS/NZS 3000 and AS/NZS 5033. Labels shall be of the type and location specified in Section 6 of AS/NZS 4777.1. Other labelling shall be as per AS/NZS 3000 and AS/NZS 5033.

4.2 Maximum System Capacity The maximum system capacity of low voltage EG connections for each subcategory shall be as follows:

1. LV EG IES (excluding ESS) connection ≤200 kVA – For LV EG connections of IES (excluding ESS), the maximum system capacity at the same connection point shall be set to less than or equal to 200 kVA

2. LV EG IES (excluding ESS) connection >200 kVA – For LV EG connections of IES (excluding ESS), the maximum system capacity at the same connection point shall be determined at the time of application but shall typically be greater than 200 kVA and less than or equal to 1000 kVA

3. LV EG non-IES connection – For LV EG connections of non-IES, the maximum system capacity shall be determined at the time of application but shall typically be greater than 0 kVA and less than or equal to 1000 kVA.

The maximum LV EG system capacity allowed for a single-phase connection is 10 kVA and is subject to individual technical assessment and power quality checks. The system capacity for low voltage EG connections on different strata titles, but at the same network connection point (e.g. retirement villages), are to be defined by the capacity at the connection point.

4.3 Generation Control Low voltage EG connections require generation control in accordance with the following.

4.3.1 Export Limits at Connection Point Export limits at the connection point of LV EG connections will be assessed as to whether it is required. Where an export limit is required or requested by the Proponent, it shall be determined at the time of application. Factors that are to be considered in determining the export limit include, but not limited to:




1. Existing asset ratings 2. Existing power quality at the relevant network location 3. Existing and forecast DER penetration at the relevant network location.

The export limit is to be interpreted as “soft”, consistent with the definition of soft export limits within AS/NZS 4777.1. The export limit is to be interpreted by the Proponent as a maximum. The ability of the Proponent’s low voltage EG system to export at the export limit is not guaranteed, but rather, it will depend upon network characteristics which change over time. The output of a low voltage EG system may need to be constrained for various scenarios including, but not limited to scenarios where power quality response modes are in operation.

4.3.1.1 Additional Export Limit Requirements Horizon Power may nominate an additional requirement for certain Proponents (or for certain towns) to install generation control devices that limits or prevents the export of energy onto the Horizon Power Electricity System. In cases where a Proponent adds an energy storage system (ESS) to an existing LV EG system, the total inverter capacity may increase beyond the maximum system capacity and export limits specified in this document, and a new application is required. Note that irrespective of how much ESS capacity is added, the site export limits specified in accordance with Section 4.3.1 shall remain applicable for such installations. The Proponent shall provide the certification from the inverter manufacturer and installer that this requirement has been incorporated as a part of their design prior to approval. Horizon Power may review the compliance of this requirement as a part of its ongoing post approval compliance checks.

4.3.1.2 Zero Export Limit Requirements In the event of network or contractual constraints, Horizon Power may nominate that the low voltage EG connection must not export any energy. In such circumstances, the maximum power spillage (power exported to Horizon Power’s grid) from the zero export systems shall not exceed 100W.

4.3.1.3 Equipment Generation control subsystems for export limiting may include but are not limited to:

• Inverter Disconnect Systems that disconnect the LV EG system if the instantaneous generation exceeds the nominated export limit.

• Inverter Output Reducer Systems that control the instantaneous generation to ensure it does not exceed the nominated export limit.

• Energy storage devices that store the excess of energy (separate or integral of the inverter).

The generation control subsystems for export limiting shall:

• Limit the export of active power to Horizon Power’s Electricity System in accordance with the nominated export limit.




• Use communication media, interfaces and protocols ensuring inter-operability of components in the subsystem.

• Meet the service life of the LV EG connection for the conditions under which it will be installed and operating.

• Be tamper-proof and settings are password protected.

4.3.2 Site Generation Limit Downstream of Connection Point Site generation limits downstream of the connection point of the LV EG connections may be applicable, and shall be determined by Horizon Power at the time of application. Those factors to be considered in determining the site generation limit include, but not limited to:

1. Retail and market operations 2. Existing asset ratings 3. Existing power quality at the relevant network location 4. Existing and forecast DER penetration at the relevant network location.

4.3.3 Balanced Generation The nominal inverter output rating of multi-phase LV EG system, or systems connected to multi-phase supply connections, shall not differ by more than 5 kVA between phases. Where multiple single-phase inverters are used they must be operated in accordance with Section 8.2 of AS/NZS 4777.2.

4.3.4 Renewable Energy Smoothing Requirements Renewable energy smoothing is required for low voltage EG connections in non-standard network areas. Controlling the ramp rate of the Inverter output is a requirement of the Renewable Energy Smoothing type of Generation Control. Renewable Energy Smoothing requires the Proponent to install an Energy Smoothing Device that provides for a gradual ramp-up or ramp-down over a period of time if the Renewable Source Electricity output changes too suddenly (ramp down is shown in Figure 1). This allows enough time for Horizon Power and Independent Power Producers to ramp up their generation assets to cover for a loss in Customer generation. The method for achieving the required ramp rate is at the discretion of the proponent.




Figure 1: Ramp Down Rate with and without Renewable Energy Smoothing

4.3.4.1 Characteristic Curve Figure 2 below plots the characteristic curve of the output power of a grid connected Inverter (for ramp down). The characteristic curve is defined as the desired output behaviour of the grid connected inverter, initially operating at nominal rated output, in response to a step change in renewable energy source output at time t = 0 seconds to 0 kW.

Renewable Energy Source Output PowerInverter Output Power with Renewable Energy SmoothingInverter Output Power without Renewable Energy SmoothingLosses

Cloud Event

Power

Time

Steady State: Inverter Output Power ≈ Renewable Energy Source Output Power

- Losses

Maximum AllowableRamp Down Rate

Ramp Down RateToo High

O0

Oss

Key




Figure 2: Ramp Down Characteristic Curve

4.3.4.2 Nominal Ramp Down Times The nominal ramp down time is depicted in Figure 2 and is defined as the time taken for the inverter to ramp down from nominal rated output to 0 kW. The nominal ramp down rate for each installation size is then derived according to the equation shown in Figure 2. For systems employing a multi-mode inverter the ramp function shall cover the customers system voluntarily reconnecting to the grid so a sudden change in system load or renewable generation is not observed by the grid. Control action is required when the ramp down rate of the renewable energy source exceeds Rn in magnitude. All LV EG connections employing System Diagrams D shall have a nominal ramp down time Tn of 720 seconds.

4.3.4.3 Nominal Ramp Up Time The nominal ramp up time Rp is defined as the time taken for the inverter to ramp up from 0 kW to nominal rated output, where:

Rp = 1000 * On / Tp [W/s]

Renewable Energy Source Output PowerInverter Output Power with Renewable Energy SmoothingLinearity BoundsLosses

Power[kW]

Time[s]

On

Tn

Rn = -1000 * On / Tn [W/s]

NL = 100 * ∆ / Tn [%] ∆

ParametersRn := Nominal Ramp Down Rate [W/s]Tn := Nominal Ramp Down Time [s]On := Nominal Rated Inverter Output [kW]∆ := Maximum Input Deviation [s]NL := Percentage Non-linearity [%]

Key




This covers for a sudden increase in Renewable Source Electricity output. Control action is required when the ramp up rate of the renewable energy source exceeds Rp in magnitude. All LV EG connections employing System Diagrams D shall have a nominal ramp up time Tp of 360 seconds.

4.3.4.4 Non-Linearity The non-linearity of the ramp rate of the inverter output, as defined by the Characteristic Curve depicted in Figure 2 shall be less than 10%. At the commencement of the ramp down period, Horizon Power may allow the inverter output to be outside this range for a period of up to 10 seconds, subject to System Impact Studies.

4.3.4.5 Method for Achieving Required Ramp Rate The ramp rate requirements describe the required output behaviour at the point of connection only. The method used for achieving the required ramp rate, such as the type and size of Energy Storage Devices, inverter control method, or load control method used together with the control algorithm, trigger condition and associated devices, is left for the Proponent to develop.

4.3.4.6 Testing The LV EG connection shall be considered to have met the ramp requirements if it passes both ramp tests described in Section 6.2.

4.3.5 Extended Ramp Rate Smoothing Requirements Extended Ramp Rate Smoothing is similar to the renewable energy smoothing described in Section 4.3.4. However, the nominal ramp down and ramp up time for extended ramp rate smoothing are greater than those specified in Section 4.3.4. All Extended Ramp Rate Systems shall have:

• a nominal ramp down time Tn of 7,200 seconds (2 hours). • a nominal ramp up time Tn of 3,600 seconds (1 hour).

The Energy Control subsystem shall:

• Have renewable energy smoothing subsystem with Extended Ramp Rates; • Have feed-in management; and • Ensure the renewable energy output seen by the Grid is free from fluctuations.

Extended Ramp Rate systems may be considered by Horizon Power for LV EG connection’s employing System Diagrams D for towns where Hosting Capacity is not available. Extended Ramp Rate systems will be considered at the discretion of Horizon Power on a case by case basis.

4.3.6 Feed-in Management Requirements Feed-in Management is a temporary control signal applied by Horizon Power to the LV EG system to lower and then raise the LV EG output power. Feed-in Management is a requirement for all LV EG connections >200kVA, and all LV EG connections in non-standard network areas.




Feed in management is not required for LV EG connections ≤200kVA in standard network areas, unless specifically nominated by Horizon Power at the time of application. This could be due to local network constraints or conditions determined at the time of application. The generation control or management of a customer’s LV EG connection may be initiated by Horizon Power, where a risk exists to power system reliability, due to contractual obligations or as required for system operational efficiencies. In certain circumstances, isolation of a Proponent’s LV EG connection may be required by Horizon Power where there is a threat to the safety of personnel or the public, or a threat to power system plant and equipment. Where feed in management is required, the Proponent shall allow Horizon Power to remotely monitor and control the low voltage EG connection in accordance with the requirements outlined in Section 4.11 – Communications Systems. The Feed-in Management subsystem shall comply with the functional requirements as outlined in Section 4.11.3, including but not limited to:

• Enable monitoring of the low voltage EG connection

• Enable remote control of the low voltage EG circuit breaker

• Enable remote control of the active power output of the low voltage EG connection

• Enable remote control of the reactive power output of the low voltage EG connection

• Enable remote control of inverter settings Each of these requirements, including the required equipment, obligations of the Proponent, and details of the communications interface is outlined in Section 4.11 – Communications Systems.

4.4 Inverter Energy System The following requirements apply to inverter energy systems:

1. The Proponent shall ensure that the low voltage EG connection is compatible with the characteristics of Horizon Power’s supply as defined in Section 2 of the Horizon Power Technical Rules.

2. The Proponent must ensure that the low voltage EG connection complies with AS/NZS 4777, AS/NZS 3100 and IEC 62109.

3. IES shall be tested by an authorised testing laboratory and be certified as being compliant with AS/NZS 4777.2 with an accreditation number

4. IES shall comprise of inverters that are registered with CEC as approved grid connect inverters

5. IES shall comprise of inverters that are tested by an authorised testing laboratory and certified as being compliant with IEC 62116 for active anti-islanding protection as per AS/NZS4777.2

6. IES shall comprise of inverters installed in compliance with AS/NZS 4777.1 7. IES shall comprise of inverters that have both volt-var and volt-watt response modes

available. 8. All LV EG connections (all inverters) shall have Modbus protocol capabilities. A

summary of the required parameters for LV EG connections is provided in Appendix N.




9. Horizon Power may require the Proponent to update inverter settings upon request.

4.5 Network Connection and Isolation Network connection and isolation requirements for IES shall be as per AS/NZS 4777.1 and AS/NZS 3000 for LV EG connections less than or equal to 200 kVA, LV EG IES connections greater than 200 kVA and LV EG non-IES connections (although AS/NZS 4777.1 currently only applies to IES systems less than or equal to 200 kVA) Network connection and isolation requirements for IES shall include but not be limited to:

1. As a minimum, mechanical isolation shall be as per AS/NZS 3000 in that the isolator must always be readily accessible

2. Any means of isolation (where lockable) shall be able to be locked in the open position only.

3. For PV systems, isolation requirements shall be as per AS/NZS 5033 Network connection and isolation requirements for Non-IES connections shall be determined by Horizon Power in the connection application stage.

4.6 Earthing The earthing requirements for low voltage EG systems shall include:

1. IES less than or equal to 200 kVA have earthing requirements as per AS/NZS 4777.1 and AS/NZS 3000.

2. IES greater than 200kVA have earthing requirements as per AS/NZS 4777.1 and AS/NZS 3000 (although AS/NZS 4777.1 currently only applies to IES systems less than or equal to 200 kVA).

3. Non-IES have earthing requirements as per AS/NZS 3000 and AS/NZS 3010 and any requirements which are additional shall be clearly stated as such.

4. For ESS, earthing requirements shall be as per AS 3011. 5. For PV systems, earthing requirements shall be as per AS/NZS 5033.

4.7 Protection

4.7.1 Inverter Integrated Protection Inverter integrated protection requirements shall be as per AS/NZS 4777.1 and AS/NZS 4777.2 for LV EG IES connections less than or equal to 200 kVA and LV EG IES connections greater than 200 kVA (although AS/NZS 4777.1 currently only applies to IES systems less than or equal to 200 kVA). Passive anti-islanding requirements and settings shall be as per AS/NZS 4777.2, with the following variations to AS/NZS 4777.2 marked with (*) and shown in the following table:




Table 8: Passive Anti-Islanding Settings

Protective Function Protective function limit

Trip delay time

Maximum disconnection

time

Undervoltage (V<) 180 V 1 s 2 s

Overvoltage 1 (V>) 265 V* 1 s 2 s

Overvoltage 2 (V>>) 265 V - 0.2 s

Under-frequency (F<) 45 Hz* 1 s 2 s

Over-frequency (F>) 53 Hz* - 0.2 s

Active anti-islanding protection requirements shall be as per AS/NZS 4777.2 and IEC 62116.

4.7.2 Central Protection Central protection requirements shall be as per AS/NZS 4777.1 for LV EG IES connections less than or equal to 200 kVA, LV EG IES connections greater than 200 kVA and LV EG non-IES connections (although AS/NZS 4777.1 currently only applies to IES systems less than or equal to 200 kVA). Table 9 provides a summary of central protection requirements, with further details as per Sections 4.7.2.1 to 4.7.2.5 of this document.

Table 9: Central Protection Requirements

Protection Requirements

LV EG IES LV EG Non-IES

≤200kVA >200kVA

Exporting Non-Exporting Exporting Non-

Exporting Exporting Non-Exporting

Grid reverse power (32R) ✓ ✓ ✓ ✓ ✓ ✓

Generator circuit Phase balance protection (46/47)

‒ ‒ ‒ ‒ ✓ ✓

Overcurrent facility fault, grid fault and earth fault protection (50/51)

✓ ✓ ✓ ✓ ✓ ✓

Passive anti-islanding protection (27U/O, 59U/O, 81U/O, 81R)

✓ ✓ ✓ ✓ ✓ ✓




Protection Requirements


≤200kVA >200kVA



Inter-tripping × × ‒ × ‒ ‒

Symbols are used to denote protection requirements, where:

✓ Represents that the protection shall be required

‒ Represents that the protection may be required × Represents that the protection shall not be required

For LV EG connections, the central protection equipment shall be located as close as practical to the Point of Supply.

4.7.2.1 Grid Reverse Power Protection Grid reverse power protection requirements shall include:

1. Reverse power protection shall be set as low as practicable with consideration of protection relay, CT accuracy and generating system synchronisation characteristics

2. The design of control systems shall minimise reverse power flow immediately following synchronisation.

Specific settings for grid reverse power protection shall be determined via a connection specific technical assessment.

4.7.2.2 Phase Balance Protection LV EG connections shall have phase balance protection in place where not inverter integrated. All Non-IES shall require both current unbalance and voltage unbalance protection. Note that three phase IES are exempt from this requirement.

4.7.2.2.1 Current Unbalance Protection

The following current unbalance requirements for the generator at the connection point shall include but not be limited to:

1. The nominal inverter output rating of multi-phase LV EG systems, or systems connected to multi-phase supply connections, shall not differ by more than 5 kVA between phases.

2. Where multiple single-phase inverters are used they must be operated in accordance with Section 8.2 of AS/NZS 4777.2.

Specific settings for current unbalance protection shall be determined via a connection specific technical assessment.

4.7.2.2.2 Voltage Unbalance Protection

Voltage unbalance limits and requirements shall be in accordance with the voltage unbalance provisions in the Horizon Power Technical Rules.




There are no voltage unbalance protection requirements in excess of the general provisions of the Horizon Power Technical Rules.

4.7.2.3 Overcurrent Facility Fault, Overcurrent Grid Fault and Earth Fault Protection Overcurrent protection must be provided at the IES isolating switch in accordance with the equipment rating. Any additional requirements for overcurrent facility fault, overcurrent grid fault and earth fault protection may be advised by Horizon Power at the time of connection.

4.7.2.4 Passive Anti-islanding Protection Passive anti-islanding settings shall be as per Table 2 of AS/NZS 4777.1, with the following variations to AS/NZS 4777.1 marked with (*) and shown in the following table:

Table 10: Central Voltage and Frequency Protection Set Points

Setting Parameter Disconnection Time

Setting

Sustained over voltage (V>) (based on average value over a period of 10min)

15 seconds 258 V*

Over voltage (V>) 2 seconds 265 V*

Under voltage (V<) 2 seconds 180 V

Over frequency (F>) 2 seconds 53 Hz*

Under frequency (F<) 2 seconds 45 Hz*

4.7.2.5 Inter-tripping Inter-tripping is not normally required for low voltage EG connections. However:

1. For LV EG connections inter-tripping may be required depending on the outcomes of technical studies

2. For LV EG Non-IES non-exporting connections, inter-tripping may not be required provided that minimum import protection is installed

3. Where there is an inter-trip, reverse power protection may not be required.

4.7.3 Interlocking Where multiple single-phase inverters are connected to more than one phase, phase balance protection as per Clause 3.4.4 of AS/NZS 4777.1 is required, with exceptions outlined within Clause 5.4.4 in AS/NZS 4777.1.

4.7.4 Power Factor Control Power factor control is not required for low voltage EG connections.




4.7.5 Synchronisation Automatic synchronising and synchronisation check requirements apply for EG Non-IES as outlined in Horizon Power Standard HPC-9OJ-13-0001-2012 - Technical Requirements for Bumpless Transfer of Customer Load between Embedded Generators and the Distribution Network.

4.7.6 Additional Requirements for LV EG Non-IES Additional protection functions apply for EG Non-IES as outlined in Horizon Power Standard HPC-9OJ-13-0001-2012 - Technical Requirements for Bumpless Transfer of Customer Load between Embedded Generators and the Distribution Network.

4.8 Operating Voltage and Frequency Horizon Power’s supply characteristics are defined in Section 2 of the Horizon Power Technical Rules. The operating voltage and frequency requirements are outlined in Section 4.7.1 – Inverter Integrated Protection. The maximum voltage set point Vnom_max is 258 V. The Proponent shall be responsible for ensuring that the maximum voltage rise within the Premises complies with AS/NZS 4777.1 and shall submit evidence for Horizon Power’s record keeping in the form of Schedule 4 – Cable Data.

4.9 Metering This section refers to the Horizon Power’s revenue metering at the Proponent’s connection point to Horizon Power’s network.

4.9.1 Approved Meters Only Horizon Power approved meters in accordance with Horizon Power Metering Standards and WA Meter Code shall be used. If the customer has existing non-conforming meters, then they shall be replaced as a part of the renewable installation at the Proponent’s cost.

4.9.2 Approved Installers The meter shall be installed by Horizon Power or its approved contractor.

4.9.3 Upgrading of Enclosure In order to meet the meter installation requirements of Section 11 of the WA Distribution Connections Manual, the Proponent may be required to upgrade the enclosure where the meters are housed.

4.9.4 Measurement of Meters Horizon Power shall perform measurements in accordance with the Metering Code and Horizon Power Metrology Procedures.

4.9.5 Cost of Metering If meter replacement is required, the cost of materials and installation of meters shall be borne by the Proponent in accordance with the customer's Buyback Contract. This includes the cost of upgrading of enclosures and switchboard if required.




4.10 Power Quality

4.10.1 Quality of Supply Low voltage EG connections shall comply with the applicable power quality requirements of the AS/NZS 61000 series as well as relevant state-based regulations and licence conditions, including but not limited to:

1. Network voltage control 2. Voltage fluctuations 3. Harmonics 4. Voltage balance.

All grid-connected inverters shall comply with the settings specified in this section. These settings may be pre-set or programmable. A summary of these settings are provided in Table 23 in Appendix F. The programming of the setting shall not be easily changed and preferably be done internally within the inverter or protected by a password. Horizon Power may request changes to the above settings prior to energisation in specific circumstances.

4.10.2 LV EG IES Power Quality Response Modes The following inverter power quality response modes as per AS/NZS 4777.2 are required:

1. Volt-Watt 2. Power Factor 3. Fixed Power Factor 4. Volt-VAr 5. Voltage Balance 6. Hz-Watt 7. Power Rate Limit

4.10.3 Volt-Watt Response Mode All inverters are required to have Volt-Watt capabilities, with these capabilities enabled by default with settings as given in Table 23 in Appendix F, and shown in Figure 3. Volt-Watt settings shall be as per AS/NZS 4777.2, with the following variations to AS/NZS 4777.2 marked with (*) and shown in the following table:




Table 11: Volt-Watt Response Reference and Maximum Set-Point Values

Reference Value Maximum value (P/Prated)

V1 207 100%

V2 220 100%

V3 254* 100%

V4 265 20%

Figure 3: Volt-Watt response curve

Horizon Power may at any time direct the enabling or disabling of Volt-Watt Response Mode or a change to the default settings.

4.10.4 Power Factor Requirements At all times during normal operation, inverters shall be capable of operating with a power factor within the range of 0.8 leading to 0.8 lagging as shown in Figure 4. The Proponent shall consider the maximum site design temperature when determining the operating ability of the inverter.




Battery Charging

P

Capacitive(leading)

Inductive(lagging)

System Exporting

0.8

Q

Inverter minimum capability

Figure 4: Power factor operational requirements for normal operation

4.10.5 Fixed Power Factor Mode All inverters are required to be capable of operating in fixed power factor mode, with these capabilities disabled by default. Refer to Table 23 in Appendix F, for required settings.

Horizon Power may at any time direct the inverter to operate in fixed power factor mode, with settings as required by Horizon Power.

4.10.6 Volt-VAr Response Mode All inverters are required to have Volt-VAr capabilities, with these capabilities enabled by default with settings as given in Table 23 in Appendix F, and shown in Figure 5.

Volt-VAr settings shall be as per AS/NZS 4777.2, with the following variations to AS/NZS 4777.2 marked with (*) and shown in the following table:




Table 12: Volt-VAr Response Reference and Set-Point Values

Reference Reference Voltage

Set-Point Value (var % rated VA)

V1 207 60% leading*

V2 230* 0%

V3 240* 0%

V4 265 60% lagging*

Figure 5: Volt-VAr response curve

Horizon Power may at any time direct the enabling or disabling of Volt-VAr Response Mode, or a change to the default settings.

4.10.7 Voltage Balance Mode All three-phase inverters, or single-phase inverters used in a three-phase system, are required to have Voltage Balance capabilities, with these capabilities disabled by default. Horizon Power may at any time direct the enabling or disabling of Voltage Balance Mode, with settings as required by Horizon Power.

4.10.8 Hz-Watt Response Mode All inverters are required to have Hz-Watt capabilities enabled by default with settings as given in Table 23 in Appendix F.




The relevant settings are in relation to the Over-Frequency Power Reduction response as described in Clause 7.5.3.1 of AS/NZS 4777.2, and include:

• Activation Frequency – this is the frequency level at which over-frequency power reduction is activated.

• Deactivation Frequency – this is the frequency level below which the over-frequency power reduction is deactivated (after a suitable delay – see the Deactivation Time) and the power level may be increased in accordance with the power rate limit.

• Deactivation Time – this is the period of time for which frequency must be below the Deactivation Frequency before the over-frequency power reduction is deactivated and the power level may be increased in accordance with the power rate limit.

• Fstop – this is the point on the Over-Frequency Power Reduction curve where the output of the system reaches zero.

The following settings are required for the Over-Frequency Power Reduction settings in non-standard network areas (i.e. outside the NWIS), in accordance with Appendix F:

• Activation Frequency: 50.6 Hz

• Deactivation Frequency: 50.5 Hz

• Deactivation Time: 20 sec

• Fstop: 53.0 Hz

Settings for standard network areas (i.e. NWIS) shall be as per Clause 7.5.3.1 of AS/NZS 4777.2. The following figure is indicative of the Over-Frequency Power Reduction response characteristic (AS/NZS 4777.2 settings shown):

Figure 6: Over frequency response (Indicative)




For systems with energy storage, additional settings are also required to enable Under-Frequency Charge Rate Limits in accordance with Clause 7.5.3.2 of AS/NZS 4777.2. The following settings are required for the Under-Frequency Charge Rate Limit settings in non-standard network areas (i.e. outside the NWIS), in accordance with Appendix F:

• Under-Frequency Activation Frequency: 49.4 Hz

• Under-Frequency Deactivation Frequency: 49.5 Hz

• Under-Frequency Deactivation Time: 20 sec

• Fstop-CH: 45.0 Hz

Settings for standard network areas (i.e. NWIS) shall be as per Clause 7.5.3.2 of AS/NZS 4777.2. The following figure is indicative of the Under-Frequency response characteristic (AS/NZS 4777.2 settings shown):

Figure 7: Under frequency response (Indicative)

4.10.9 Power Rate Limit Modes All inverters are required to have a Soft Ramp Up after Connect or Reconnect mode as per AS/NZS 4777.2 Section 6.3.5.2. Horizon Power only requires for Soft Ramp Up to be applied to reconnection (i.e. ramp up / soft start). The ramp up power rate limit shall be:

WGra+=16.67% of rated power per minute.




4.10.10 LV EG Non-IES Synchronous Power Quality Response Synchronous LV EG Non-IES connections shall be designed and operated to adequately control real and reactive power output through either of the following power quality response modes:

1. Voltage control mode OR

2. Fixed power factor mode. The required power quality response mode and settings shall be determined depending on the outcomes of technical studies.

4.11 Communications Systems This section identifies the communications systems requirements for LV EG connections. Communications is a requirement for all LV EG connections >200kVA, and all LV EG connections in non-standard network areas. Communications is not required for LV EG connections ≤200kVA in standard network areas, unless specifically nominated by Horizon Power at the time of application. This could be due to local network constraints or conditions determined at the time of application. Where communications is required, the Proponent shall allow Horizon Power to remotely monitor and control the low voltage EG connection in accordance with the requirements outlined in this section.

4.11.1 Communications – Horizon Power Obligations Horizon Power shall undertake the following in relation to the communications subsystem:

• Supply an approved and preconfigured gateway device which will be owned by the Proponent.

• Own and maintain the communications channel (upstream of the gateway device) and any SIM card associated with the communications subsystem.

• Confirm commissioning of the communications subsystem.

• Perform control and monitoring of the low voltage EG installation output.

4.11.2 Communications – Proponent Obligations Where communications is required, the Proponent shall:

• Allow Horizon Power to remotely monitor and control the low voltage EG connection.

• Provide active communication between the LV EG connection and Horizon Power via an approved gateway device and Horizon Power’s communication infrastructure.

• Provide a single phase 240 V AC power supply adjacent to the LV EG system for the gateway device.

• If the Proponent intends to also connect the inverter directly to their LAN, the Proponent shall ensure this is done only if a suitable additional network port or wifi connection is available. The primary inverter Ethernet connection must be connected to a terminated socket inside the Inverter Comms enclosure.




• Configure the inverter to provide suitable control and monitoring inputs to Horizon Power’s gateway device. Horizon Power requires that all low voltage EG connections (including all inverters that make up the LV EG system) have Modbus TCP protocol capabilities. The inverters must comply with the Modbus mapping table in Appendix N.

• Install and commission the Horizon Power provided gateway device, liaising with Horizon Power as required.

• Own and maintain the Horizon Power provided gateway device and any associated wiring and accessories. The Proponent is responsible for all costs associated with replacement of the gateway device.

• Complete Appendix O – On Site NextG Cellular Signal Strength Checklist and return the result to Horizon Power.

• Complete Appendix P – LV EG Connection Control System Information Sheet and return to Horizon Power.

• Provide Horizon Power with full and unrestricted access to the low voltage EG connection, main switchboard, and any power supply, network connection, or gateway device installed as part of the low voltage EG connection, to perform up front and ongoing works.

4.11.3 Communications Functional Requirements The communications subsystem shall comply with the functional requirements as outlined in Table 13.

Table 13: Communications Functional Requirements

Requirement Description Mandatory (Y/N)

Monitoring Monitoring the output of supported inverters. Make the data listed in section 4.11.4 available to Horizon Power.

Y

Monitoring for Batteries

Additional monitoring is required for installations with batteries, as detailed in section 4.11.4.

Y

Control – System Disconnection & Reconnection

Disconnect and reconnect the LV EG system from the network.

Y

Control Gross Output

Receiving a signal from Horizon Power, controlling the active power gross output of the LV EG system including both PV generation and batteries.

Y

Loss of Communications – Gross Setpoint

Default to safe level of active power gross output in the event of loss of communications with Horizon Power.

Y

Control Nett Export Receiving a signal from Horizon Power, controlling the active power nett export onto the grid from the Proponent’s Premises, as measured at the connection point for that Premises.

N

Control Reactive Power Output

Receiving a signal from Horizon Power, controlling the reactive power output of the LV EG system.

N




Requirement Description Mandatory (Y/N)

Control of Batteries Ability to enable and disable energy storage charging from the grid.

Ability to initiate charging and discharging of batteries.

N

Loss of Communications – Nett Setpoint

Default to safe level of active power nett export in the event of loss of communications with Horizon Power.

N

Loss of Communications – Reactive Power Setpoint

Default to safe level of reactive power output the event of loss of communications with Horizon Power.

N

Control of Inverter Settings

Allow remote updates to inverter settings in accordance with Horizon Power’s Technical Requirements for Distributed Energy Resources

N

4.11.4 Monitoring the Output of Inverters Where feed in management is required, Horizon Power requires the following signals to be monitored and sent back via Horizon Power’s SCADA interface. Monitoring must be made available at a summary level information for the Premises. The monitoring signals for each subcategory of installation include, but are not limited to, the following:

Table 14: Monitoring Requirements

Requirement Units Description Mandatory (Y/N)

Circuit Breaker Status

- Current circuit breaker status of the LV EG system (connected / disconnected)

Y

Heartbeat Counter - This is an analogue signed integer heartbeat signal produced internally by the Proponent’s LV EG monitoring and control system. It is required to be incremented by one every second.

Y

Power kW Gross active power produced by the LV EG system in kW.

Y

Power Setpoint % Gross active power setpoint received by the LV EG system in %.

Y

Default Power Setpoint

kW Default gross active power setpoint of the LV EG system upon loss of communications to Horizon Power (kW)

Y

Default Gross Power Limit Readback

% Default gross active power setpoint of the LV EG system in %.

Y





Active Gross Power Limit Readback

% Gross active power setpoint of the LV EG system in %.

Y

Ramp Rate %/s Ramp rate for moving from one setpoint to a new setpoint in %/second.

Y

Reactive Power kVAr Reactive power produced by the LV EG system in kVAr.

Y

Apparent Power kVA Apparent power produced by the LV EG system in kVA.

Y

Total AC Current A The total AC current exported / imported by the LV EG system.

Y

Phase A Voltage V Phase A voltage of the LV EG system in Volts (V). Y

Phase B Voltage V Phase B voltage of the LV EG system in Volts (V). Y

Phase C Voltage V Phase C voltage of the LV EG system in Volts (V). Y

Power Factor - Power factor of the LV EG system. Y

Frequency Hz Frequency of the LV EG system in Hz. Y

Energy Export kWh The total energy exported at the connection point in kWh.

Y

Energy Import kWh The total energy imported at the connection point in kWh.

Y

Nett Export Power kW The total active power exported at the connection point in kW.

Y

Nett Import Power kW The total active power imported at the connection point in kW.

Y

Inverter settings - Configuration of inverter settings N

Battery power rating kW Battery rated total power capacity N

Battery energy rating kWh Battery rated total available energy N

Power kW Battery active power N

Battery SOC % Current battery State of Charge (SOC) / available energy

N

Battery status - Charge status of storage device (charging / discharging / idle)

N





Battery voltage V Internal battery voltage N

4.11.5 Controlling the LV EG Circuit Breaker The LV EG circuit breaker must be able to be remotely controlled by Horizon Power. Appendix B outlines the connection arrangements and single line drawings applicable for low voltage EG connections, including location of circuit breakers. Appendix L provides additional information regarding the configuration of the Proponent’s LV EG system to communicate via the SCADA interface. A pulse on digital command signal shall be sent via Horizon Power’s SCADA interface to the Proponent’s LV EG system gateway device to open / trip the circuit breaker. A separate pulse on digital command shall be sent to close the circuit breaker. The LV EG system circuit breaker open and close status signals are required to be readable by the LV EG system either as hardwired digital inputs or communications digital inputs (via protection relay). The digital Trip LV EG system Isolation Point command is a pulse output signal issued by the SCADA interface to trip the LV EG system isolation point. Note that the actual isolating function is performed by the local LV EG control system. The digital Close LV EG system Isolation Point command is a pulse output signal issued by the SCADA INTERFACE to close the LV EG system isolation point. Note that the actual isolating function is performed by the local LV EG system control system.

4.11.6 Controlling the Active Power Output of Inverters The following signals will be issued for control of Low voltage EG systems via Horizon Power’s SCADA interface:

• Setpoint – Maximum % gross output as measured at the terminals of the low voltage EG system (%)

• Setpoint – Transition ramp rate (% gross output per second) from one output level to the next.

The LV EG system shall ramp the power output of the inverter(s) to the power setpoint advised by Horizon Power at a ramp rate to be configured by Horizon Power. The transition ramp rate shall be sent as a parameter via Horizon Power’s SCADA interface. The configurable ramp rate enables the target setpoint to be achieved without causing a sudden step change in the power station load. When any new LV EG connection is commissioned, it must be initially configured with a transition ramp rate equal to the renewable smoothing ramp rate advised in Section 4.3.4.

4.11.7 Controlling the Reactive Power Output of Inverters Reactive power control for Low voltage EG installations is not mandatory at this stage. In some circumstances, Horizon Power may advise that reactive power control is required. In these cases, the Proponent’s LV EG connection monitoring and control system must respond to the following signals, issued via Horizon Power’s SCADA interface:




• Setpoint – Reactive power output as measured at the terminals of the Low voltage EG system (kVAr)

The Proponent shall control system output as per the set-points provided.

4.11.8 Data Sampling Frequency Where feed in management is required for LV EG connections:

• The frequency for data sampling will be 1 minute intervals.

• All data shall be timestamped. Information regarding latency requirements for provision of this data to the Horizon Power is outlined in Section 4.11.16 – Communications System Performance Requirements.

4.11.9 Response Time for Control Signals The response time for control signals shall be determined from the time the signal is posted via Horizon’s SCADA interface to the time confirmation is received via Horizon’s SCADA interface.

4.11.10 Availability Information regarding availability requirements for the communications system is outlined in Section 4.11.16 – Communications System Performance Requirements.

4.11.11 Control & Communication Interfaces Horizon Power’s SCADA interface is used for connection of individual Low voltage EG installations to Horizon Power’s DERMS. Further details of Horizon Power’s SCADA interface may be found in Appendix L.

4.11.12 Loss of Communications to Horizon Power For Low voltage EG installations, Horizon Power will provide the LV EG system with the following data:

• Heartbeat counter – an analogue signed integer produced by Horizon Power’s DERMS that is incremented by one every second.

• Default (safe state) gross power setpoint (%)

• Setpoint – Transition ramp rate (% gross output per second) from one output level to the next.

The heartbeat counter and default setpoint are transmitted to local LV EG control system via the SCADA interface. In the case of communication loss to Horizon Power, the heartbeat counter will stop incrementing.

If the heartbeat counter is unchanged for 60 seconds, the LV EG system shall ramp the power output of the system to the default power setpoint advised by Horizon Power, at the transition ramp rate as outlined in Section 4.11.6. The configurable ramp rate enables the target setpoints to be achieved without causing a sudden step change in the power station load.




If the communications to Horizon Power is re-established (heartbeat value updated), the LV EG system shall restore the power output of the system to the power setpoint in existence before the communications loss, at the transition ramp rate.

In some circumstances, these signals may be erroneously set to zero during certain loss of communication situations. The local LV EG control system is to hold the last good values and ignore zero values during the loss of communication. When any new LV EG system is commissioned, it must be initially configured with a transition ramp rate equal to the renewable smoothing ramp rate advised in Section 4.3.4.

4.11.13 Installations with Multiple Inverters Where an installation consists of multiple inverters, that is combinations of PV inverters, or battery inverters, the Proponent shall aggregate the parameters of the multiple inverters. The Proponent shall provide these aggregated parameters as read, and where applicable write values that can be accessed/set by Horizon Power. Where a control set-point is provided by Horizon Power, the Proponent shall coordinate the aggregated inverters to ensure that they respond correctly to the set-point provided by Horizon Power. Horizon Power will only interface with one LV EG control system per site.

4.11.14 Equipment The communication subsystem shall comprise the following components:

• An approved gateway device with hardwired connection to the inverter system, including provision of dedicated single phase 240 V AC power for the gateway device.

• One or more cabinets (with a minimum of IP24 or higher to suit local conditions) to house the above components. Installation shall be away from direct sunlight.

• Installation shall be robust, as reasonably practicable, to discourage the people from tampering with the approved gateway device and its connection to the inverter.

• The Proponent shall declare to Horizon Power the name and model of CEC approved inverters that it proposes to monitor and control (Supported Inverters).

• All Low voltage EG systems (all inverters) shall have Modbus protocol capabilities. A summary of the required parameters for Low voltage EG installations is provided in Appendix N. The Proponent must provide all Modbus register information for the proposed installation.

4.11.15 Gateways The following requirements apply for gateways utilised as part of the communications system:

1. Only Horizon Power supplied gateway devices shall be used. 2. Horizon Power shall supply the approved gateway device at the Proponent’s cost. 3. The gateway device shall be pre-programmed by Horizon Power. 4. The gateway device shall be installed by a CEC accredited installer.

4.11.16 Communications System Performance Requirements




Where communications is required, the following performance requirements shall be met: Table 15: Communications System Performance Requirements

Requirement % Accuracy2 Latency3 Availability4

Monitoring ±10% 5min 99.9% Control Gross Output ±10% 1min 99.9% Control Nett Export ±10% 1min 99.9%

Loss of Communications setpoints ±10% 1min 99.9%

Control – System Isolation ON/OFF 15sec 99.9% Monitoring of Batteries ±10% 5min 99.9%

Control of Batteries ±10% 1min 99.9%

Control of Inverter Settings ±1% 5min 99.9%

4.12 Data and Information

4.12.1 Static Data and Information The Proponent is to provide static data and information to Horizon Power as per Appendix D.

4.12.1.1 Summary of Documentation to be Submitted The following documentation shall be supplied by the Proponent as part of their application:

• Completed Application Form;

• Compliance Checklist (Schedule 1);

• System Diagram (Schedule 2);

• Circuit Diagrams (Schedule 3);

• Cable Data (Schedule 4);

• System Parameters (Schedule 5);

• NER Signoff (Schedule 6); and

• Static Data and Information as per Appendix D. Upon receipt of the application and all required information, Horizon Power shall undertake a Network Impact Assessment (NIA) and a detailed System Impact Study (SIS). The SIS fees shall apply.

2 Accuracy requirements for Low voltage EG systems must be met for 99.97% of the time. 3 Latency describes the period of time from the time the signal is posted via Horizon Power’s SCADA interface to the time confirmation is received via Horizon’s SCADA interface. 4 System availability including network availability.




Additional information is required to undertake a SIS, details of which are included in Appendix H. Examples of the Schedules to be submitted are included in the Appendices and Schedules.

4.12.1.2 Schedules to be submitted Schedule 1: Compliance Checklist A checklist comprising the key elements that needs to be satisfied in order to comply with this Document. Schedule 2: System Diagram A conceptual diagram that illustrates the functional relationships between key subsystems using solid lines. The Proponent’s System Diagram shall be in accordance with Appendix B of this Document. Schedule 3: Circuit Diagram One or more diagrams detailing the electrical connections from the point of connection through to the EG energy source. The Proponent’s Circuit Diagram shall be in accordance with Schedule 3 and the other requirements of this Document. The circuit diagram submitted to Horizon Power for reference shall include:

• Electrical connections for all phases.

• Neutral and earth connections (AC & DC).

• Switchboard electrical connections including depiction of proponent final loads.

• Electrical interconnection of all electrical elements of the LV EG connection including inverters, energy storage devices, chargers, renewable energy sources, DC and AC protection devices, protection functions, meters.

Schedule 4: Cable Data Data associated with power cables connecting the Proponent’s grid connected inverter to Horizon Power’s electricity distribution system. This includes the consumer mains cable. Cable data to be provided includes:

• Location of cable in installation

• Number of cores

• Cross sectional area and insulation type

• Cable Length

• Method of installation (e.g. underground in conduit) The cables shall be depicted via one or more concept diagrams. Refer to example at the end of this Document. Schedule 5: System Parameters The Proponent is to capture the key parameters (including power quality response modes and protective functions) that will be implemented for their system. Schedule 6: NER Signoff For all Low voltage EG installations, a NER accredited engineer shall validate that the design is in accordance with this Document. An installer may reuse a NER declaration for multiple




installations providing the installations do not differ with the NER validated reference design in the following elements:

• Make and model of inverters

• Installed EG and ESS (where required for renewable energy smoothing) capacity

• System Diagram

• Circuit Diagram (changes to protection and cable sizes permitted)

• Electrical arrangement of LV EG connection.

• Changes to firmware that affect compliance with this Document.

• Changes to equipment that affect compliance with this Document.

• Changes to the type of technology or methodology used to achieve compliance with this Document.

If a NER declaration is reused, a cover letter shall be supplied stating:

• The project and date of the reference design

• That the new project does not differ from with the NER validated design in the elements described above.

Sample letters for NER declaration and declaration reuse are contained in Schedule 6.

4.12.2 Dynamic Data and Information No dynamic data and information requirements apply for LV EG systems, beyond those requirements in Section 4.11 – Communications.

4.13 Cybersecurity Where communications is required, Horizon Power shall notify the proponent of any cybersecurity requirements, which may include:

1. Monitoring and communications devices shall be in screw sealed or lockable enclosures 2. Protection and control from the network systems (firewalls) 3. Privilege settings and password protection 4. Limiting access to only that which is required to monitor the generating unit. 5. Communications shall be over secured channels or Modbus TCP. 6. No unauthorised changes to the SGD

4.14 Technical Studies Technical Studies are required to be completed as part of the connection application as per Table 16 and as per jurisdictional requirements.




Table 16: Technical Studies Required for LV EG Connections

Technical Studies


≤200kVA >200kVA



Voltage level (inc. power factor) ✓ ✓ ✓ ✓ ✓ ✓

Power flow ✓ ✓ ✓ ✓ ✓ ✓

Fault level ✓ ✓ ✓ ✓ ✓ ✓

Protection grading ‒ ‒ ✓ ✓ ✓ ✓

Symbols are used to denote technical studies requirements, where:

✓ Represents that the study shall be required

‒ Represents that the study may be required × Represents that the study shall not be required

These technical studies shall be completed by Horizon Power. The criteria, relevant inputs, relevant outputs, and information requirements for system studies are provided in Appendix H. Where one or more of the technical studies does not meet the assessment criteria, Horizon Power shall provide the proponent with an alternative option which may include:

1. Alternative configurations of the generating systems (e.g. lower generation control limits) 2. Network augmentation (and associated cost of network augmentation).

4.15 Systems with Energy Storage Energy Storage Systems (ESS) may be installed by the Proponent and shall comply with the requirements in this section. Horizon Power’s requirement for renewable energy smoothing may necessitate the installation of an ESS. ESS installed for renewable energy smoothing and shall comply with Section 4.15.1. ESS may be installed by the Proponent for purposes other than renewable energy smoothing.

4.15.1 Energy Storage for Renewable Energy Smoothing ESS for renewable energy smoothing shall comply with the following:

• Only for the purposes of undertaking routine testing of the Energy Storage Device and ramp rates in accordance with Section 6.2, as well as for cycling of the Energy Storage Device system to maintain optimal health, it is permissible that the Energy Storage Device system is charged from the grid.




• The maximum frequency for which Energy Storage Device charging from the grid is permissible is:

o Two cycles annually for ramp rate testing; and o One cycle per month (in aggregate) for the purposes of battery health cycling.

• Charging of Energy Storage Devices shall be in accordance with Section 4.15.2. Horizon Power does not permit arbitrage. Any Proponent found to be charging Energy Storage Devices from the grid not in accordance with these requirements, may have their LV EG system disconnected from the grid until the system is shown to have been modified to meet these requirements. For systems with Energy Storage installed for smoothing, the grid connected Inverter shall be prevented from exporting power until the Energy Storage Devices have sufficient energy stored to meet the ramp rate requirements described in Section 4.3.4. For systems with Energy Storage installed for smoothing and Export Limit requirements, the grid connected Inverter shall not supply power to the local load until the Energy Storage Devices have sufficient energy stored to meet the ramp rate requirements described in Section 4.3.4.

4.15.2 Charging of Energy Storage Devices from the Grid Where charging of Energy Storage Devices from the grid is permitted by Horizon Power, this shall be in accordance with AS/NZS 4777.2, Sections 6.3.5, 6.4.3 and 7.5.3.2, with voltage and frequency setpoints provided in Appendix F. Horizon Power may at any time direct the enabling or disabling of energy storage system charging, with settings as required by Horizon Power.




5 FEES AND CHARGES Horizon Power’s fees and charges for low voltage EG connections are shown in Table 17 below.

Table 17: Horizon Power Fees and Charges for LV EG Connections

Note however, additional costs may be incurred in the event the Network Impact Assessment or System Impact Study identifies the requirement for any generation or network augmentation, communications, or augmentation of the Proponent’s EG system required to facilitate the EG connection.

Type of Application Technical Assessment Required Information

Horizon Power Fees

Low voltage EG connection

(standard network area without feed in

management or renewable energy

smoothing)

Network Impact Assessment & System Impact Study

Application form with Schedule 1,2,3,4,5 and 6

System Model Information

refer Appendix H

SIS Fees apply

Low voltage EG connection with

feed in management

and/or renewable energy smoothing

Network Impact Assessment & System Impact Study

Application form with Schedule 1,2,3,4,5 and 6

System Model Information

refer Appendix H

SIS Fees apply

Test Witnessing Charges apply

Feed in

Management Gateway Charges

apply




6 TESTING AND COMMISSIONING Testing and commissioning requirements for LV EG connections are as per Table 18 including:

1. Testing and commissioning plans shall be produced by the Proponent and may be required to be signed off by Horizon Power prior to finalising the connection agreement.

2. Testing and commissioning acceptance shall be signed off either by a NER Engineer, or by a Horizon Power-approved suitably qualified person.

3. Testing and commissioning acceptance may require Horizon Power to carry out witnessing.

4. For IES, testing and commissioning requirements shall be in accordance with AS/NZS 4777.1, AS/NZS 3000, AS/NZS 3017 and AS/NZS 5033 (where applicable), the equipment manufacturer’s specifications and Horizon Power’s technical requirements to demonstrate that the LV EG IES system meets the requirements of the connection agreement. Compliance to AS/NZS 3000 and AS/NZS 5033 (where applicable) may be tested by suitably qualified local electrical authorities.

5. For Non-IES, testing and commissioning requirements shall be in accordance with the equipment manufacturer’s specifications and Horizon Power’s technical requirements to demonstrate that the LV EG non-IES system meets the requirements of the connection agreement.

6. The Proponent shall retain a complete set of manuals, installation drawings; permits, inspection and verification test reports and make them available to Horizon Power if requested.

Table 18: Testing and Commissioning Requirements for LV EG Connection

Testing and commissioning requirements


≤200kVA >200kVA



Protection settings and performance

✓ ✓ ✓ ✓ ✓ ✓

Power quality settings and performance

✓ ✓ ✓ ✓ ✓ ✓

Export limits settings and performance

✓ ✓ ✓ ✓ ✓ ✓

Communications settings and performance

‒ ‒ ✓ ✓ ✓ ✓




Shutdown Procedures × × ✓ ✓ ✓ ✓

Confirm system is as per specifications

✓ ✓ ✓ ✓ ✓ ✓

Confirm SLD is located on site ✓ ✓ ✓ ✓ ✓ ✓

Renewable smoothing ‒ ‒ ‒ ‒ ‒ ‒

Symbols are used to denote testing and commissioning requirements, where:

✓ Represents that the testing and commissioning item shall be required

‒ Represents that the testing and commissioning item may be required × Represents that the testing and commissioning item shall not be required

6.1 Type Testing of Renewable Energy Smoothing Systems For installations where Renewable Energy Smoothing is required, Horizon Power needs to be able to verify whether a Proponent’s LV EG system complies with both the ramp down and ramp up requirements specified in Section 4.3.4. This is achieved by the validation of an NER accredited engineer that the Renewable Energy Smoothing system is in accordance with the ramp testing requirements specified in Section 6.2. Horizon Power reserves the right to witness testing or request evidence of testing results.

6.2 Routine Testing of Renewable Energy Smoothing Systems Annually from the date of commissioning it is a requirement that the results of one of the test methods outlined in Section 6.2.1 are provided to Horizon Power. The results may be provided manually or be automated from the inverter/battery controller. Validation is achieved by Horizon Power certifying that the ramp rate requirements are being met. Results are to be sent to [email protected]

6.2.1 Testing Method The testing method shall be one of the following:

Table 19: Types of Test Methods

Test Method Description

Pushbutton 5 Self-Test A pushbutton is pressed which initiates a test sequence that results in a PASS or FAIL.

5 A pushbutton may be a multifunction, accessible by menus or dedicated button




Battery Health Indicator An indicator guaranteeing the health of the battery system and showing there is sufficient capacity in the battery system to perform the test sequence

6.2.2 Ramp Testing Procedure Figure 8 illustrates the test requirements. In addition, an example of test measurements is contained in Appendix A. Note that two consecutive ramp up and down tests are to be performed to check consistency and repeatability.

Figure 8: Example of Ramp Down Test Measurements Where Result is TEST FAIL

Procedure: 1. Measure inverter output power prior to commencement of test, O0

Let On be the nominal output rating of the grid connected inverter Let K = O0 / On

Renewable Energy Source Output PowerDesired Inverter Output Power Ramp Down CurveLinearity Bounds (Pass Bounds)LossesMeasured Value

Power[kW]

Time t[s]

O0 = K*On

Tn

ParametersTn := Nominal Ramp Down Time [s]On := Nominal Rated Inverter Output [kW]O0 := Measured Inverter Output @ t=0 [kW]K := O0 / On [units]

Key

On

Outside of PassBounds

0.1KTn 0.3KTn 0.5KTn 0.7KTn 0.9KTn

NOT TO SCALE




If K < 0.4 abort test6 2. Determine 5 (example) test points and the pass bounds for each power

measurement. Note Horizon Power may require additional test points if the system total output is too low.

Table 20: Test Points

Measuring Time

Power Measurement Pass Bounds

Lower Upper

0.1 KTn 0.8 KOn KOn

0.3 KTn 0.6 KOn 0.8 KOn

0.5 KTn 0.4 KOn 0.6 KOn

0.7 KTn 0.2 KOn 0.4 KOn

0.9 KTn 0 0.2 KOn

3. Electrically isolate the renewable energy source from the rest of the Renewable

Energy Installation7. 4. Start timer. 5. Record measured inverter output value Omeasured at each test point specified in

step 2. 6. If all five measured output values Omeasured are within the pass bounds specified

in step 2 then TEST PASSED, else TEST FAILED 7. Indicate Status 8. If TEST FAILED disconnect inverter from grid according to Section 6.2.5.

If TEST PASSED, allow permanent connection to the grid to Section 6.2.5. 9. Reconnect the renewable energy source to the rest of the Renewable Energy

Installation. 10. Test Complete

6.2.2.1 Alternative Ramp Testing Procedure In certain circumstances, Horizon Power will require monitoring over a period of time to validate compliance with the ramp rate curves. This may be done as an alternative test for installations where witness of smoothing tests is not practical (e.g. cloud prediction technologies).

6 The best time to perform the test is during peak output (typically. 12-2pm) 7 This could be done by sending an energising signal to a relay that actuates the DC breaker immediately upstream of the renewable energy source.




Horizon Power will require a data capture resolution rate of no less than 2 seconds for this procedure.

6.2.3 Measurement Accuracy Each measured value shall be accurate to within 4% and with repeatability of 2%.

6.2.4 Recording of Data Test data shall be stored in an electronic format that guards against tampering. Data associated with the previous 12 ramp down tests shall be able to be stored. Data shall include:

• Date and time of test.

• Test result: Pass or Fail.

• Five test measurement values.

• Values of K, Tn, O0, On at the time of the test.

6.2.5 Action on Test Completion The Proponent may connect their LV EG system to Horizon Power’s Electricity System for the purposes of conducting the ramp down test, with permission from Horizon Power. This is a temporary connection only. The table below describes the action required once a test result is obtained.

Table 21: Action Required Once Test Result Obtained

Method Action on TEST FAIL Action on TEST PASS

Pushbutton Self-Test Automatic Disconnection of Inverter.

Permanent Connection of LV EG system to Horizon Power Grid not allowed and prevented by software interlock.

Permanent Connection of LV EG system to HP Grid now allowed

Battery Health Indicator Conduct a Pushbutton Self-Test

NA

6.3 Testing and Commissioning of Communications Systems

6.3.1 Test Objectives The tests must ensure the communications system performs within the performance requirements of Table 15.




6.3.2 General Test Requirements The following general requirements apply to any Proponent who conducts testing of a communications system:

• The supply of test results shall include: a) a brief log showing when tests were done (site, time, date, test alphanumeric

identification); b) plots of system measurements, appropriately annotated; c) relevant schematics of equipment and the local system configuration, including

details of the system configuration at the start of, end of, and any other appropriate time during the test sequence; and

d) test data in Microsoft Excel spreadsheets, including lists of any data collected manually.

• Provide information in advance of the tests including: a) A detailed schedule of tests to be completed as agreed by Horizon Power. For

more information on the required tests, refer to Appendix H. The schedule must list the tests, when each test is to occur and whose responsibility it will be to perform the test.

b) Schematics of the LV EG connection plus any descriptive material necessary to draw up/agree upon a schedule of tests.

c) Most up to date relevant technical data and parameter settings of equipment.

• Provide a minimum of 15 business day prior notice of test commencement to Horizon Power for the purpose of arranging witnessing of tests.

• Horizon Power’s representative must be consulted about proposed test schedules, be kept informed about the current state of the testing program, and give permission to proceed before each test is carried out.

• Unless agreed otherwise, tests must be conducted consecutively.

• Test result data must be presented to Horizon Power within 10 business days of completion of each test or test series.

• Where test results show that the system performance does not comply with Section 4.11.16 it will be necessary to rectify problem(s) and repeat the tests.

• All Factory Acceptance tests and reports shall be approved by an accredited engineer listed on the Australian National Engineering Register.

6.3.3 Commissioning and Site Acceptance Tests (SAT) Site acceptance tests apply to all new LV EG connections. The required site acceptance tests are outlined in Appendix Q – Communications Systems Schedule of Tests. Site acceptance tests shall be conducted during field commissioning of the LV EG system. As a minimum, Horizon Power requires the mandatory tests outlined in Appendix Q to be completed for low voltage EG systems.




The Proponent must provide evidence to demonstrate the tests meet the performance requirements of Table 15, including required ramp rates. Horizon Power will witness all testing at its discretion to ensure the Proponent meets the requirements of this document. The commissioning sheets for Low voltage EG communications systems shall be completed as follows:

• Communications signal strength (at LV EG) checklist. This is to be completed by the Proponent and returned to Horizon Power. Refer to Appendix O

• LV EG control system information sheet. This is to be completed by the Proponent and returned to Horizon Power. Refer Appendix P

• Communications system commissioning checklist. This will be completed by Horizon Power.

6.3.4 Ongoing Testing

6.3.4.1 Routine Testing No Routine Testing of the Communications system is required by Horizon Power at this time.

6.3.4.2 Non-routine Testing Horizon Power may on an ad hoc basis inspect or require testing of LV EG monitoring and control systems to re-confirm its correct operation and continued compliance with this document.

6.4 LV EG System Commissioning Commissioning and verification shall be in accordance with section 8 of AS/NZS 3000, AS/NZS 5033 (if applicable), WADCM, WA Electrical Requirements and manufacturer specifications. In addition, if applicable, the Proponent shall perform a ramp down and/or ramp up test prior to the commencement of use. Horizon Power reserves the right to witness commissioning or request evidence of commissioning results. Commissioning may require the involvement of Horizon Power personnel as part of the commissioning process.




7 OPERATIONS AND MAINTENANCE Low voltage EG systems should be operated and maintained to ensure compliance with their connection agreement and all legislation, codes, and/or other regulatory instruments at all times. Horizon Power may inspect the Proponent’s low voltage EG system at any time. This inspection will be at Horizon Power’s cost. Operations and maintenance requirements for LV EG connections shall include, but not be limited to:

1. An operation and maintenance plan shall be produced and the Horizon Power may require for it to be signed off prior to forming a connection agreement

2. The LV EG system shall be operated and maintained to ensure compliance with the connection agreement and all legislation, codes, and/or other regulatory instruments at all times

3. Operation and maintenance reports may be required by Horizon Power at a specified interval no more frequently than annually

4. The electrical installation at the supply address shall be maintained in a safe condition 5. The Proponent shall ensure that any changes to the electrical installation at the supply

address are performed by an electrician lawfully permitted to do the work and that the Proponent holds a Certificate of Compliance issued in respect of any of the changes

6. The Proponent shall seek Horizon Power approval prior to altering the connection in terms of an addition, upgrade, extension, expansion, augmentation or any other kind of alteration, including changing inverter settings.

7.1 Compliance Audits The EG system shall comply with the Technical Requirements at all times, until it is permanently disconnected. The Proponent shall notify Horizon Power when the EG is permanently disconnected. Horizon Power may undertake audits of the EG system for compliance with the requirements of this Document. Note that compliance audits of existing EG systems connected prior to this version of the Technical Requirements may also be undertaken; these systems shall be assessed against the version of the Technical Requirements at the time the system was approved to connect to the grid. Horizon Power will contact the Proponent to arrange for an audit of the EG system at their Premises. The Proponent shall provide full unrestricted access to the EG system to the Horizon Power personnel or authorised Horizon Power contractor undertaking the audit. The results of the audit will be recorded on Horizon Power’s system for future reference. Should the audit identify non-compliance with the Technical Requirements, a Fault Note will be placed on the installation, with the EG system disconnected from Horizon Power’s network. The EG system will not be reconnected to the grid until Horizon Power is satisfied that the non-compliance has been resolved. Rectification of non-compliance issues shall be at the Proponent’s cost. The frequency for audits will not be more than once per year, with exceptions where non-compliance has previously been identified for the EG connection at the same Premises.




APPENDIX A. DEVIATIONS FROM THE NATIONAL DER CONNECTION GUIDELINES

This appendix shall include a register of all deviations from this technical guideline in the format provided in Table 22.

Table 22: Table of Deviations from National DER Connection Guidelines

Section Description of Deviation Type of Deviation Justification

N/A

Note that, consistent with provisions under the Energy Networks Australia National DER Connection Guidelines, Horizon Power has the following additional requirements:

• Alternative inverter settings are required in accordance with Appendix F to cater for voltage and frequency fluctuation characteristics of Horizon Power’s systems (ref Appendix F);

• Additional Renewable Energy Smoothing requirements in non-standard network areas to cater for power station constraints in Horizon Power’s systems (ref section 4.3.4); and

• Additional Communications requirements in non-standard network areas to cater for power station constraints in Horizon Power’s systems (ref sections 4.3.6 and 4.11).




APPENDIX B. CONNECTION ARRANGEMENT REQUIREMENTS Section 4 nominates the System Diagram that is applicable to the proponent’s LV EG connection. A system diagram illustrates the functional relationships between key subsystems using solid lines. The lines do not represent wiring, rather energy flows between subsystems. Details such as intermediary protection devices, chargers, internal device connections, switches and links are not displayed on the provided system diagrams. The Proponent’s Electrical Installation shall be in accordance with one of the following system diagrams:

• System Diagram D (LV EG connection with communications and smoothing); • System Diagram E (LV EG connection with communications);

(Note that System Diagram A, B and C are no longer applicable and have been removed from this document.) Common elements to both system diagrams include, but are not limited to:

• A single point of connection between the Proponent’s Electrical Installation and Horizon Power’s Low Voltage Grid.

• Splitting of the Proponent’s Electrical Installation into the following elements: - DER - Proponent Final Loads - One or more switchboards - Tariff Meter and sub meters

• The DER may include, but is not limited to the following devices: - Renewable Energy Sources (e.g. photovoltaic cells, wind turbine) - Grid Connected Inverter - Other Inverters (if required) - Chargers - Grid Protection Devices - Energy Storage Devices (e.g. battery bank) - Feed-in Management Devices - Associated control, monitoring, protection and auxiliary equipment (e.g.

gateway devices) • Final Proponent Loads

- Final Proponent Loads requiring energy - Associated control, monitoring, protection and auxiliary equipment




System Diagram D: LV EG connection with Communications and Smoothing System Diagram D is represented in Figure 9 below:

Figure 9: System Diagram D - Generation Managed with Communications and Smoothing

Key elements of System Diagram D are:

• Use of Communications and Smoothing devices (see Sections 4.11 and 4.3.4).

• Requirement for Energy Storage devices to be installed either on the DC or AC side of the grid connected inverter or other intermediary devices.

• Direct communication required between the Proponent’s Electrical Installation and Horizon Power’s Control System.

• No direct connection is permitted between the Proponent’s LV EG system and Proponent Final Loads. The connection must be made via the switchboard.

Note: the feed-in management and/or smoothing subsystems may be integral or separate with the grid-connected inverter. Where an installation requires feed in management, the gateway device shall communicate with only one interfacing device to provide the feed-in-management signal to the Proponent’s renewable energy system. Where an installation consists of multiple inverters, the communications with the gateway device (refer to Section 4.11.15) shall be through a PLC or suitable equivalent device that aggregates the parameters from multiple inverters. The design and installation of the aggregation system is the Proponent’s responsibility.




System Diagram E: LV EG connection with Communications

System Diagram E is represented in Figure 10 below:

Figure 10: System Diagram E – LV EG connection with Communications

Key elements of System Diagram E are:

• Use of Communications (see Section 4.11). • The energy storage device or renewable energy smoothing is not a

mandatory requirement. It may be added by the Proponent as long as the export limit requirements in Section 4.3.1 are addressed.

• No direct connection is permitted between the Proponent’s LV EG system and Proponent Final Loads. Connection must be made via the switchboard.

Note: the feed-in management subsystem may be integral or separate with the grid connected inverter.




APPENDIX C. MODEL STANDING OFFER (CONNECTION AGREEMENT)

The REBS product is offered on a ‘net export’ basis. Please refer to Horizon Power’s website for Eligibility Calculator and associated ‘Terms and Conditions’ for REBS product details.




APPENDIX D. STATIC DATA AND INFORMATION This appendix includes the static data and information that is required to be provided by the Proponent to Horizon Power, including as a minimum: 1. NMI meter numbers (10 digit) 2. DER Devices

a) Fuel source – primary {renewable/biomass/waste; fossil; hydro; geothermal; solar; wave; wind; tidal; storage}

b) Fuel source – descriptor c) Make, model and manufacturer d) Maximum capacity (kW or MW) e) Storage capacity (kWh/MWh of available storage) f) Installer g) Whether the device is remotely controllable (Y/N) h) Compliance with Australian Standards

3. Inverter a) Make, model and manufacture b) Whether the installer has changed the inverter default manufacturer settings (Y/N)

with details of any changes c) Maximum capacity (kW and kVA) d) Date of installation e) Compliance with Australian Standards

4. Inverter enabled modes of operation a) Demand response modes enabled and enablement method b) Power quality modes {power response (frequency control); voltage response

(voltage-watt or voltage-var); Q (reactive power), PF (power factor)} 5. Trip settings

a) Frequency trip settings {over-frequency, under frequency} b) Voltage trip settings {over-voltage, under-voltage} c) Other protection functions and settings




APPENDIX E. LIST OF AMENDMENTS TO PREVIOUS VERSION This document includes the following amendments since the previous version:

Section Affected Clause Type of Change

Note

Initial document incorporating ENA National Connection Guidelines.

This document supersedes standard HPC-9FJ-12-0001-2012.

Notes: [1] 'New addition' refers to the addition of a new clause not available in previous version of document [2] 'Amendment to Existing' refers to modifications made to a clause in previous version of document [3] The table above is not an exhaustive list of all changes made to this document




APPENDIX F. SUMMARY OF INVERTER SETTINGS The following settings are required for inverters connected to Horizon Power’s systems The settings are in accordance with AS/NZS 4777.2:2015, with any variations to the standard settings marked with (*).

Table 23: Summary of Required Inverter Settings

AS/NZS 4777.2:2015 Clause Description AS/NZS 4777.2:2015

Default setting Horizon Power required settings

6.2 Inverter demand response modes DRM 0 Disconnect - required.

DRM 1 to DRM 8 - optional.

DRM 0 implemented as required by Horizon Power.

DRM 1 to DRM 8 - not required.

6.3 Power quality response modes

6.3.2.2 Volt-Watt response mode Default - enabled. Required by all inverters. Enabled for all inverters.

Settings: 1Ø / 3Ø

V1 = 207 / 359

V2 = 220 / 381

V3 = 254* / 440*

V4 = 265 / 459

Volt-watt response active power setpoints in accordance with Table 10 of AS/NZS 4777.2.

6.3.2.3 Volt-VAr response mode Default - enabled. Required by all inverters. Enabled for all inverters.

Settings: 1Ø / 3Ø

V1 = 207 / 359

V2 = 230* / 398

V3 = 240* / 415

V4 = 265 / 459

Volt-var response reactive power setpoints as follows:

Setpoints (VAr % rated VA)

V1 | 60% leading*

V2 | 0

V3 | 0

V4 | 60% lagging*

6.3.2.4 Voltage balance mode Default - disabled. Disabled for standard connections.

As directed by Horizon Power, enabling of this mode may be requested.






6.3.3 Fixed power factor mode and reactive power mode

Default - disabled. Disabled for standard connections.


6.3.4 Power factor curve -Cos φ (P) Default - disabled. Disabled for standard connections.


6.3.5 (6.3.5.3.2 )

6.3.5.3.2

Power rate limit (Ramp Rate)

Modes:

(a) Soft Ramp Up after connect or reconnect

Note: This will be applied to reconnection (i.e. ramp up/soft start)

.

Required.

Required.

As per this Document

Ramp Up:

WGra+= 16.67% of rated power per minute

Protective functions for connection to electrical installations and the grid

7.3 Active anti-islanding protection Required. Test method to IEC 62116 is required

7.4 Passive anti-islanding protection Required Frequency:

fmin = 45 Hz

fmax = 53 Hz

Voltage:

1Ø / 3Ø

Vmin= 180 / 312 V

Vmax= 265 / 459 V

7.5.2 Sustained operation for voltage variations

Required. Required.

1Ø / 3Ø

Vnom-max = 258 V* / 447 V






7.5.3.1 Sustained operation for frequency variations – Response to an increase in frequency

Required. The following settings are required for Over-Frequency Power Reduction8 in non-standard network areas (i.e. outside the NWIS):

Activation Frequency = 50.6 Hz*

Deactivation Frequency = 50.5 Hz*

Deactivation Time = 20 sec*

Fstop = 53 Hz*

Settings for standard network areas (i.e. NWIS) shall be as per Clause 7.5.3.1 of AS/NZS 4777.2.

7.6 Disconnection by external signal. Required. Required.

Implemented as directed by Horizon Power for individual connections.

7.7 Connection and reconnection procedure

Required. Required.

Frequency to be maintained within 47.5 Hz to 50.5 Hz*

Additional requirements for multiple mode inverters

6.3.5.3.4 Power rate limit (Ramp Rate)

(c) Changes in energy source operation.

Note: This will be applicable to multiple mode (hybrid) inverters with energy storage

.

. Enabled.

Ramp Down:.

WGra – = 8.33% of rated power per minute

(12 min ramp down rate)

Ramp Up:

WGra+= 16.67% of rated power per minute

(6 min ramp up rate)

8 The relevant settings in relation to the Over-Frequency Power Reduction settings as described in Clause 7.5.3.1 of AS/NZS 4777.2, include: • Activation Frequency – this is the frequency level at which over-frequency power reduction is activated. • Deactivation Frequency – this is the frequency level below which the over-frequency power reduction is

deactivated (after a suitable delay – see the Deactivation Time) and the power level may be increased in accordance with the power rate limit.

• Deactivation Time – this is the period of time for which frequency must be below the Deactivation Frequency before the over-frequency power reduction is deactivated and the power level may be increased in accordance with the power rate limit.

• Fstop – this is the point on the Over-Frequency Power Reduction curve where the output of the system reaches zero.






6.4.3 Volt watt response mode for charging of energy storage

Required. Required.

Settings:

1Ø / 3Ø

V1= 180 / 312 V

V2= 220 / 381 V

V3= 254* / 440 V*

V4= 265 / 459 V

Volt-watt response active power setpoints in accordance with Table 12 of AS/NZS 4777.2.

7.5.3.2 Sustained operation for frequency variations – Response to a decrease in frequency (charging of energy storage)

Required The following settings are required for Under-Frequency Charge Rate Limits in non-standard network areas (i.e. outside the NWIS):

Activation Frequency = 49.4 Hz*

Deactivation Frequency = 49.5 Hz*

Deactivation Time = 20 sec*

Fstop-CH = 45 Hz*

Settings for standard network areas (i.e. NWIS) shall be as per Clause 7.5.3.2 of AS/NZS 4777.2.




APPENDIX G. EXAMPLE OF RAMP TESTS

G1. EXAMPLE RAMP DOWN TEST Table 24: Example Ramp Down Test Parameters

Description Parameter Value

Nominal Rated Inverter Output On 5 kW

Nominal Ramp Down Time Tn 720 s9

Initial Inverter Output O0 4.57 kW

Calculated Scaling Constant K 0.914

Measurement Error ε 4%

Table 25: Example Ramp Down Test Data

Test Point

Measuring Power Measurement Pass Bounds Pmeasured

(kW) Omeasured (%)

Result Time (s) Lower (%) Upper (%) [error range]

t1 63 80 100 4.57 91

PASS [87.36-94.64]

t2 189 60 80 3.43 69

PASS [66.24-71.76]

t3 315 40 60 1.90 38

FAIL [36.48-39.52]

t4 441 20 40 1.75 35

PASS [33.6-36.4]

t5 567 0 20 1.05 21

PASS [20.16-21.84]

9 Note that AS/NZS 4777.2 specifies a different default nominal ramp down time




Figure 11: Example Ramp Down Test Results

G2. EXAMPLE RAMP UP TEST Table 26: Example Ramp Up Test Parameters

Description Parameter Value

Nominal Rated Inverter Output On 100 kW

Nominal Ramp Up Time Tn 360 s10

Initial Inverter Output O0 0.0 kW

Measurement Error ε 4%

10 Note that this ramp up time is the same as set by default in AS/NZS 4777.2

0

10

20

30

40

50

60

70

80

90

100

0 60 120 180 240 300 360 420 480 540 600 660 720

Pow

er [P

/Pra

ted

%]

Time [s]

Ramp Down Test Results

Measured

Lower Pass Bound

Upper Pass Bound




Table 27: Example Ramp Up Test Data

Test Point

Measuring Power Measurement Pass Bounds Pmeasured

(kW) Omeasured (%)

Result Time (s) Lower (%) Upper (%) [error range]

t1 27 0 0 0 91

PASS [7.68-8.32]

t2 88 14.4 34.4 26.0 69

PASS [24.96-27.04]

t3 142 29.4 49.4 43.0 38

PASS [41.28-44.72]

t4 208 47.8 67.8 74.0 35

FAIL [71.04-76.96]

t5 293 71.4 91.4 88.0 21

PASS [84.48-91.52]

Figure 12: Example Ramp Up Test Results

0

10

20

30

40

50

60

70

80

90

100

0 40 80 120 160 200 240 280 320 360

Pow

er [P

/Pra

ted

%]

Time [s]

Ramp Up Test Results

Measured

Lower Pass Bound

Upper Pass Bound



Uncontrolled document when printed. Printed copy expires one week from print date. Refer to CS10 for current version.

APPENDIX H. HORIZON POWER SERVICE AREA Horizon Power’s service area is shown in the figure below. The NWIS covers the area between Karratha and Port Hedland and surrounding suburbs.

Figure 13: Horizon Power Service Area map showing NWIS




APPENDIX I. SYSTEM IMPACT STUDY MODEL REQUIREMENTS Horizon Power undertakes system impact studies for Low voltage EG installations to ensure the effect of those installations on the power system are appropriately managed. As part of these studies, the following events and associated boundary conditions are investigated:

• Normal system operation

• Installation energisation and trip scenarios

• System cloud events

• Fault ride through scenarios

• Network voltage and loading assessment

• Fault levels and harmonics assessment

For each of these cases, the effect on system frequency, voltage, loading, and other power quality parameters are assessed. Horizon Power conducts these studies in DigSilent PowerFactory. Model Requirements Horizon Power requires a suitable power system simulation model for each type of inverter proposed, which is able to adequately represent the performance of the installation for each of the scenarios and events considered above. The model should be a configured model that includes parameters and settings that the proponent intends to use. The model shall be supplied with an instruction manual and description of the control philosophy of the LV EG system. The model shall have the following functionality:

- Run for steady state, dynamic (RMS), and harmonic simulations. - Able to adjust active power, reactive power and voltage setpoints in steady state

model. - Able to adjust active power, reactive power and voltage parameters in dynamic

model. - Include frequency out of limit trip settings in accordance with Horizon Power’s

Technical requirements and AS/NZS 4777, including ability to set trip time delays. - Include voltage out of limit trip settings in accordance with Horizon Power’s

Technical requirements and AS/NZS 4777, including ability to set trip time delays. - Include frequency vs watt droop response in accordance with Horizon Power’s

Technical requirements and AS/NZS 4777, including ability to set droop response time delays and parameters.

- Include voltage vs watt droop response in accordance with Horizon Power’s Technical requirements and AS/NZS 4777, including ability to set droop response time delays and parameters.




- Include voltage vs var droop response in accordance with Horizon Power’s Technical requirements and AS/NZS 4777, including ability to set droop response time delays and parameters.

The model shall be provided in a DigSilent PowerFactory11 file with the inverter connected to a single machine infinite bus. The model shall contain step load and bus fault cases which demonstrate suitable performance of the RMS simulation, including satisfactory initialisation of controller initial conditions. Default parameter settings for all common and composite models for the inverter system shall be included. A technical user guide (instruction manual) shall be provided with the model. This shall include key parameters with a sufficient description of each parameter. The following table outlines the parameters which must be able to be adjusted within the dynamic plant model:

Type Setting Description Units Default Value

Dynamic model setpoints

Pset Active power setpoint kW -

Qset Reactive power setpoint kVAr -

Qmax Max reactive power kVAr -

Qmin Min reactive power kVAr -

Vset Voltage setpoint p.u. 1.0p.u.

Sfault_max Maximum short circuit contribution MVA -

Anti-islanding dynamic model setpoints

fmax Maximum frequency anti-islanding setting

Hz 53Hz

fmin Minimum frequency anti-islanding setting

Hz 45Hz

Tfreq_disconnect Anti-islanding frequency trip time delay

s 2s

Tfreq_reconnect Anti-islanding frequency reconnection time delay

s 2s

Vmax Maximum voltage anti-islanding setting

p.u. 1.10p.u.

Vmin Minimum voltage anti-islanding setting

p.u. 0.75p.u.

Tvolt_disconnect Anti-islanding voltage trip time delay s 2s

11 Contact Horizon Power to confirm version of DIgSILENT PowerFactory currently in use.





Tvolt_reconnect Anti-islanding voltage reconnection time delay

s 2s

Volt-watt droop response dynamic model setpoints

V1_volt_watt Volt-Watt Response Mode voltage V1

p.u. 0.86p.u.


p.u. 0.92p.u.


p.u. 1.06p.u.


p.u. 1.10p.u.

P1_volt_watt Volt-Watt Response Mode power setpoint

% 100%


% 100%


% 100%


% 20%

Volt-VAr droop response dynamic model setpoints

V1_volt_var Volt-Watt Response Mode voltage V1

p.u. 0.86p.u.

V2_volt_ var Volt-VAr Response Mode voltage V2 p.u. 0.96p.u.

V3_volt_ var Volt- VAr Response Mode voltage V3

p.u. 1.00p.u.

V4_volt_ var Volt- VAr Response Mode voltage V4

p.u. 1.10p.u.

Q1_volt_ var Volt- VAr Response Mode reactive power setpoint

% 60%


% 0%


% 0%


% -60%





Hz-Watt droop response dynamic model setpoints

fstop_hz_watt Hz-Watt overfrequency response maximum frequency setpoint

Hz 53Hz

fstart_hz_watt Hz-Watt overfrequency response starting frequency setpoint

Hz 50.25Hz

Pstop_hz_watt Hz-Watt overfrequency response maximum frequency power setpoint

% 0%

Pstart_hz_watt Hz-Watt overfrequency response starting frequency power setpoint

% 100%

fstop_CH_hz_watt Hz-Watt underfrequency response minimum frequency setpoint

Hz 45Hz

fstart_CH_hz_watt Hz-Watt underfrequency response starting frequency setpoint

Hz 49.75Hz

Pstop_CH_hz_watt Hz-Watt underfrequency response minimum frequency power setpoint

% 0%

Pstart_CH_hz_watt Hz-Watt underfrequency response starting frequency power setpoint

% 100%

Note that the operating power, reactive power, and voltage setpoints must be accessible and updated via parameter events within the PowerFactory RMS module. Inverter harmonic current and flicker emission levels must be included in the inverter model. The model should also include relevant protection relays and settings to simulate the performance of the PV system during power system disturbances. This includes, but is not limited to, under and overvoltage protection, under and over-frequency protection etc. In addition to power system simulation model, the following information is also required for Horizon Power to undertake System Impact Studies:

• Maximum and minimum load at facility (active power and reactive power / power factor).

• Proposed arrangement and site layout of the installation.

• Single line diagram of proposed LV EG system.

• Typical 24 hr load power curve measured at 15 minute intervals or less.

• Inverter capability curves




APPENDIX J. PRE-COMMISSIONING DATA This data shall be provided by the proponent (for all Low voltage EG Systems) at least 4 weeks prior to commissioning date:

• Letter to Horizon Power stating all approval conditions are met;

• Proponent’s inverter and mains protection settings;

• Inverter’s fault ride through capabilities and settings;

• Commissioning Plan; and

• Operation & Maintenance Manual.




APPENDIX K. POST COMMISSIONING DATA This data shall be provided by the Proponent (for all Low voltage EG Systems) within six weeks from commissioning date:

• LV EG system ramp down and ramp up performance results;

• Confirmation of commissioning of feed-in-management system (if applicable); and

• Flicker and Harmonics assessment results.




APPENDIX L. HORIZON POWER’S SCADA INTERFACE System Overview The following figure shows the high-level system diagram of a Low voltage EG System connected to Horizon Power’s DERMS via Horizon Power’s SCADA interface12.

UTILITYEXPORT/IMPORT

METER

DER CIRCUIT BREAKERBREAKER STATUSTRIP/CLOSE SIGNALS

SOLAR SYSTEM MAIN BUS

INVERTER 1 INVERTER 2 INVERTER 3

CENTRAL CONTROL SYSTEM

HORIZON POWER BUS

HP ROUTER

HORIZON POWER FIM PLC

OUTPUT SETPOINTSYSTEM VALUES

Control / Communications

Hardwire

3G/ LTE

The system contains the following key elements: 1. Gateway device issued by Horizon Power, which provides the LV EG system a single

point of interface to the Horizon Power SCADA Network. Details of the gateway device and associated installation guide is provided in Appendix M.

2. The Proponent’s LV EG Control System device that interfaces with the LV EG system equipment, and communicates with Horizon Power via the Horizon Power gateway device.

3. An export/import meter that provides the LV EG control system with the export/import data13.

4. A main isolation point / circuit breaker. 5. Inverter(s) or array(s) of inverters that can receive and ramp to achieve the power

output setpoint issued by the LV EG control System directly or indirectly via any sub-

12 The figure above is an indicative layout only. It should be read in conjunction with AS/NZS 3000, AS/NZS 4777.1 and WADCM. 13 The export/import meter must be provided by the customer. The Horizon Power utility meter may not be used for this purpose.

Horizon Power

DERMS

Horizon Power

Gateway

S C O

Site

LV EG Control System




control system devices. The inverters used in the LV EG system shall comply with the requirements of this Document.

6. Where an installation consists of multiple inverters, the communications with the gateway device shall be through a single PLC or suitable equivalent device that aggregates the parameters from multiple inverters (the LV EG Control System). The design and installation of the aggregation system is the Proponent’s responsibility.

Hardware Requirements The Proponent’s LV EG Control System can be any type of smart control system device but preferably a Programmable Logic Controller (PLC) that is able to:

1. Communicate MODBUS TCP/IP protocol as a Server (Slave) device to Horizon Power DERMS.

2. Communicate with the Export/Import Meter to collect metering data. 3. Communicate with the LV EG system circuit breaker or main protection relay unit to

read breaker status (open/close) and send remote operation commands (trip/close). 4. Send active power setpoint to the inverter(s) or array(s) of inverters, directly or

indirectly via any sub-control systems. 5. Perform all logical calculations required to meet the functional requirements of the

system.

Communication parameters The Proponent’s LV EG Control System is required to communicate MODBUS TCP/IP protocol with Horizon Power as a server (slave) device.

The MODBUS slave ID should be set to 1.

The LV EG Control System is required to reserve 40 consecutive MODBUS holding word registers (16 bits) for communications with Horizon Power’s DERMS.

Word 0 to 29 are for output data to the DERMS.

Word 30 to 39 are for input data from the DERMS.

Further details regarding the required MODBUS parameters for Low voltage EG installations is provided in Appendix N.




APPENDIX M. COMMUNICATIONS GATEWAYS Horizon Power will provide each Low voltage EG system with a pre-programmed gateway device that is equipped with a NextG SIM card. Each SIM card is assigned a unique phone number and an IP address that is registered in the Horizon Power SCADA Network. This SIM card remains the property of Horizon Power at all times.

Each remote LV EG system site will be provided with a pre-programmed Cybertec Series 2000 3G Modem, external antenna, surge arrestor and extended coaxial cable. The modem is pre-loaded with a Horizon Power Telstra 3G SIM card and configuration file. Each SIM card is assigned with a unique phone number and IP address that is recognisable by the Horizon Power SCADA Network.

The Cybertec Modem provides a single point interface for the LV EG control system to Horizon Power’s DERMS via Horizon Power’s SCADA network. The Cybertec Modem, antenna, surge arrestor and coaxial cable are installed by the customer and is connected to the local LV EG system local network switch.

Cybertec Series 2000 Modem Gateway

Proponent’s Requirements The Proponent is required to:

1. Perform the On-site NextG Cellular Signal Strength checklist (refer to Appendix O) and return the result to Horizon Power. Based on the results, a suitable type of antenna and associated mounting equipment will be provided.

2. Install and connect the provided external antenna on the roof of the kiosk / cabinet / enclosure well clear of any obstructions and if possible, in direct line of sight to the nearest cellular base station or base station.

3. Install, connect and power the provided Cybertec Modem Router with a direct current (DC) power source in the voltage range of +12VDC to +60VDC. The DC power source must be fed by a stable power source backed by UPS or battery. It is a requirement that the DC power source supplying the modem remains permanently energised. The Cybertec 3G Modem Router is required to be installed within a fully enclosed environment that is protected from unfavourable weather conditions.




4. Connect the Cybertec Modem to the LV EG Control System device or a network switch that has connectivity to the LV EG Control System device, using a standard CAT6 RJ45 Ethernet cable or higher. The CAT6 Ethernet cable is to be supplied by the Proponent.

5. Complete the LV EG Control System Information sheet (refer to Appendix P) and return the result to Horizon Power.

Hardware The following table details the list of materials supplied by Horizon Power for Low voltage EG systems.

Item Description Unit Quantity

1 Cybertec Series 2000 Modem Router

Each 1

2 Cybertec Series 2000 Modem Router Quick Start Guide

Each 1

3 Horizon Power NextG SIM card Each 1

4 External Antenna Each 1

5 External Antenna Cable Each 1

Gateway Installation Guide

MODEM ROUTER

(FRONT VIEW)(REAR VIEW)

+10VDC to +60VDCDC Power Source

KIOSK / ENCLOSURE ROOF

EXTERNAL ANTENNA

EXTERNAL ANTENNA CABLE

Network Switch Central Control System

ETHERNET CABLE

Cybertec Series 2000 3G Modem Router Connection Diagram (2155 Model)

Installation Steps: 1. Install the external antenna on the roof of the kiosk/cabinet well clear of any

obstructions and if possible, in direct line of sight to the nearest cellular base station.

DER Control System




2. Install the Cybertec 3G Modem Router onto a DIN rail using the provided DIN rail clips. The Modem can also be mounted to a panel or tray by means of screws.

3. Connect one end of the antenna cable to the external antenna and the other end to the Main Antenna (SMA) port on the rear panel.

4. Power the Cybertec 3G Modem Router with +12 VDC to +60 VDC DC power source. 5. Connect the Cybertec Modem earth stud on the rear panel to an earthing point. 6. Connect the Ethernet cable (minimum CAT 6) from the Modem LAN port 1 on the

front panel to the local network switch that has connectivity to the LV EG Control System device. Alternatively, the Modem LAN port 1 can be connected directly to the LV EG Control System device.

7. Refer to the Cybertec Series 2000 Modem Quick Start Guide that comes with the Modem for more information.




APPENDIX N. REQUIRED MODBUS PARAMETERS For Low voltage EG systems, the Horizon Power DERMS communicates with remote LV EG control systems using Modbus TCP/IP Protocol where the DERMS is the client and LV EG system is configured as server. The LV EG system is required to receive Control Setpoints in the same format as the following table unless otherwise specified.

It is the LV EG system’s responsibility to convert the provided scaled analogue values into any specific formats. For example the Feed in Management (FIM) power setpoint value of 6021 with the scale factor of 100 is equivalent to 60.21 %.

As a minimum, the following control Modbus parameters are required for Low voltage EG inverters:

Low voltage EG System Control (Input) Data Table

Holding Register

Bit Data Type

Scale Factor

Unit Description

30 0 BOOL LV EG System Circuit Breaker Open Command

1 BOOL LV EG System Circuit Breaker Close Command

2-15 BOOL Spare

31 0-15 BOOL Spare

32 INT16 1 Heartbeat Counter

33 INT16 100 % Gross Power Limit Setpoint

34 INT16 100 % Default (Comms fail) Gross Power Limit Setpoint

35 INT16 100 %/s Gross Power Limit Ramp Rate

36-39 Spares

Note the first two words are reserved for digital output signals and the remaining 8 words are for analogue outputs.

The LV EG system is also required to provide Horizon Power with a list of System Monitoring Data in the same format as the following table unless otherwise specified.

All the analogue values are required to be in the engineering units and scale as detailed in the following table (unless otherwise specified). For example, the current value of 1.25 A with scale factor of 100 should be 125.

As a minimum, the following control Modbus parameters are required for Low voltage EG inverters:




Low voltage EG System Monitoring (Output) Data Table

Holding Register

Bit Data Type

Scale Factor

Unit Description

0 0 BOOL LV EG System Circuit Breaker Open

1 BOOL LV EG System Circuit Breaker Closed

2-15 BOOL Spare

1 0-15 BOOL Spare

2 INT16 1 Heartbeat Counter

3 INT16 100 % Received Gross Power Setpoint

4 INT16 100 A Total AC Current

5 INT16 100 V Phase A Voltage

6 INT16 100 V Phase B Voltage

7 INT16 100 V Phase C Voltage

8 INT16 100 Power Factor

9 INT16 100 Hz Frequency

10-11 INT32 100 kW Gross Active Power (Low word first)

12-13 INT32 100 kVAr Reactive Power (Low word first)

14-15 INT32 100 kVA Apparent Power (Low word first)

16-17 UINT32 1 kWh Energy Export (Low word first)

18-19 UINT32 1 kWh Energy Import (Low word first)

20-21 INT32 100 kW Nett Export Active Power

(Low word first, Nett export from LV EG site to grid represents a positive value)

22 INT16 100 % Default Gross Power Limit Readback

23 INT16 100 % Active Gross Power Limit Readback

24-29 Spare

Note the first two words are reserved for digital signals and the remaining 28 words are for analogue inputs.




APPENDIX O. ON SITE NEXTG CELLULAR SIGNAL STRENGTH CHECKLIST

The purpose of this check list is to measure the relative Telstra NextG 850MHz (3G) field signal strength of the proposed installation location for the Horizon Power gateway device. Based on the recorded results on this check list, a suitable signal receiver will be selected for the optimised performance. Site Name: _____________________________________________________________ Address: _______________________________________________________________ Assessed By ____________________________________________________________ Contact Number _________________________________________________________ Date ___________________________________________________________________




APPENDIX P. LV EG CONTROL SYSTEM INFORMATION SHEET The purpose of this information sheet is to record all the required information regarding the LV EG Control System. The information will be used to by Horizon Power to configure the Cybertec Modem Router and DERMS. Site Name: _____________________________________________________________ Address: _______________________________________________________________ Assessed By ____________________________________________________________ Contact Number _________________________________________________________ Date ___________________________________________________________________ Ongoing Site Contact Details These are the details of the customer’s nominated site representative after the LV EG system has been approved to connect to Horizon Power’s grid. Horizon Power may contact the site representative if any issues are observed with the LV EG system, or if the LV EG system is required to be isolated for any reason. Name: _________________________________________________________________ Contact Number: _________________________________________________________ Email Address:___________________________________________________________




Item No Item Value

DER Central Control System Hardware

1 Make / Manufacture

2 Model

DER Central Control System Communications

3 IP Address of the Modbus Module / Port

4 Modbus Device ID (Typically 1)

5 Modbus Port Number (Typically 502)

6 Starting Modbus Holding Register for HP FIM Communication (in the 400000 range). Refer to Appendix - Communications Gateways

7 Ending Modbus Holding Register for HP FIM Communication (in the 400000 range). Refer to Appendix - Communications Gateways

8 IP Address to be allocated to Horizon Power Router. This needs to be in the same network with the DER Central Control System




APPENDIX Q. COMMUNICATIONS SYSTEMS – SCHEDULE OF TESTS

14 Normal operation is where all elements of the LV EG system are in service, the LV EG system is producing normal output of between 75%-100% of rated kW, and no active curtailments are in place.

Test No

General Description Changes Applied Test Conditions

Mandatory Tests (Y/N)

Site Acceptance Tests

M1 Monitor gross output - Normal operation14 5min

Y

M2 Monitor nett export - Normal operation 5min with load in service

Y

M3 Monitor connection status

LV EG system On/Off Normal operation

Y

M4 Monitor other mandatory parameters as detailed in section 4.2

- Normal operation 5min

Y

M5 Monitor battery parameters as detailed in section 4.2

(a) normal operation 5min

(b) charging 5min

(c) discharging 5min

Battery initial SOC 60% to 85%

Y

C1 Control of LV EG circuit breaker

LV EG system On / Off Ramp the LV EG system to minimum load or 0kW.

Y

C2 Control of gross output LV EG system or VPP gross output set to:

(a) 0% rated kW

(b) 25% rated kW

(c) 50% rated kW

(d) 75% rated kW

(e) 100% rated kW

LV EG system initial output 75% to 100%

Y

C3 Communications fail – inverter defaults to gross output setpoint

Upon comms loss, LV EG system or VPP gross output set to:

(a) 0% rated kW

(b) 25% rated kW

(c) 50% rated kW

(d) 75% rated kW

(e) 100% rated kW


Y




C4 Control of nett export LV EG system or VPP nett export set to:

(a) 0% rated kW

(b) 25% rated kW

(c) 50% rated kW

(d) 75% rated kW

(e) 100% rated kW


N

C5 Communications fail – inverter defaults to nett export setpoint

Upon comms loss, LV EG system or VPP nett export set to:

(a) 0% rated kW

(b) 25% rated kW

(c) 50% rated kW

(d) 75% rated kW

(e) 100% rated kW


N

C6 Control of reactive power LV EG system or VPP reactive power set to:

(a) +30% rated kVAr

(b) -30% rated kVAr

(c) +60% rated kVAr

(d) -60% rated kVAr

(e) +100% rated kVAr

(f) -100% rated kVAr

LV EG system power output 75% to 100% of rated kW throughout test

LV EG system initial reactive power output 0%

N

C7 Communications fail – inverter defaults to reactive power setpoint

Upon comms loss, LV EG system or VPP reactive power set to:

(a) +30% rated kVAr

(b) -30% rated kVAr

(c) +60% rated kVAr

(d) -60% rated kVAr

(e) +100% rated kVAr

(f) -100% rated kVAr

LV EG system power output 75% to 100% of rated kW throughout test

LV EG system initial reactive power output 0%

N

C8 Control of batteries - initiate charging and discharging of batteries, and disable energy storage charging from the grid.

(a) charging 5min

(b) discharging 5min

(c) repeat (a) and (b) and demonstrate disabled charging from the grid

Battery initial SOC 60% to 85%

N




SCHEDULES

The following Schedules shall be submitted to Horizon Power by the Proponent as part of their application:

• Schedule 1 Proponent Compliance Checklist

• Schedule 2 System Diagram (example included below)

• Schedule 3 Circuit Diagram (example included below)

• Schedule 4 Cable Data (example included below)

• Schedule 5 System Parameters

• Schedule 6 NER Sign off (example included below)



Uncontrolled document when downloaded. Refer to CS10 for current version

SCHEDULE 1. PROPONENT COMPLIANCE CHECKLIST

System Diagram: E D Comments

Description Clause Complies Complies

Export Limit 4.3.1 □ □

Balanced Generation 4.3.3 □ □

Renewable Energy Smoothing 4.3.4 N/A □

Extended Ramp Rate Smoothing 4.3.5 N/A □

Feed in Management 4.3.6 □ □

Inverter Energy System 4.4 □ □

Network Connection and Isolation 4.5 □ □

Earthing 4.6 □ □

Protection Requirement 4.7 □ □

Passive anti-islanding 4.7.2.4 □ □

Horizon Power Meter at Property 4.9 □ □

Volt-Watt Response 4.10.3 □ □

Power Factor Requirements 4.10.4 □ □

Volt-VAR Response 4.10.6 □ □

Volt-Hz Response 4.10.8 □ □

Communications Systems 4.11 □ □

Schedule 2 4.12.1.2 □ □

Schedule 3 4.12.1.2 □ □

Schedule 4 4.12.1.2 □ □

Schedule 5 4.10 □ □

Schedule 6 4.12.1.2 □ □

Cybersecurity 4.13 □ □



Uncontrolled document when downloaded. Refer to CS10 for current version

System Diagram: E D Comments

Description Clause Complies Complies

Systems with Energy Storage 4.15 □ □

Testing and Commissioning 6 □ □

Operations and Maintenance 7 □ □




SCHEDULE 2. SYSTEM DIAGRAM *****SAMPLE ONLY****




SCHEDULE 3. CIRCUIT DIAGRAM *****SAMPLE ONLY****

SHEET 1

Note: For indicative purposes only - the Proponent shall rely on the other requirements of this Document together with AS/NZS 4777.1, AS/NZS 3000, AS/NZS 5033 (PV only) and other applicable documents to connect the internal components of Renewable Energy Installation correctly

POINT OF CONNECTION

HORIZONPOWERMETER

HP NETWORKSingle Phase240V a.c

AN

METER FUSE

MAINSWITCH(rating)

INVERTERMAIN SWITCH& OVER CURRENTPROTECTION(rating)

Neutral Link

Earth LinkMEN

MainEarth

A

N

To Customer FinalLoads

A

N

MAIN SWITCHBOARD

{To Renewable EnergyInstallation(SHEET 2)




(Schedule 3 continued) *****SAMPLE ONLY****

SHEET 2

INVERTER 1(with grid protection device)

A

N } From MainSwitchboard(SHEET 1)

INVERTER LOCALISOLATOR (a.c)(rating)

Epv+pv-

PV ARRAYISOLATOR (d.c)(rating)PV ARRAY

pv+pv-

batt+

batt-

BATTERYCB (d.c)(rating)

Battery

(no of strings, cells per string,Power per cell)

(Voltage, Ampere-Hours)




SCHEDULE 4. CABLE DATA *****SAMPLE ONLY**** Concept Drawings (Sample):

MAIN SWITCHBOARD& METER INVERTER

PROPERTYBOUNDARY

CUSTOMERPOLE

HORIZONPOWERPOLE

1

2

3

RENEWABLEENERGY SOURCEINVERTERMAIN SWITCHBOARD/

METER BOXCUSTOMER POLEHORIZON POWERPOLE

123

Property Boundary




(Schedule 4 continued) ****NOTE: Include cable information for all power cables between Inverter and Point of Supply****

Concept Drawing Item

Cable Length Cable Type Installation type

1 10m 6mm2 , 2 Core + Earth, PVC/PVC, Copper

In Roof Space

2 20m 6mm2 , 2 Core, PVC/PVC, Copper Underground

3 30m 6mm2 , 2 Core, Bare, Copper Overhead




SCHEDULE 5. SYSTEM PARAMETERS

kVA

V1 VoltsV2 VoltsV3 VoltsV4 Volts

V1 VoltsV2 VoltsV3 VoltsV4 Volts

V1 leading V2 0V3 0V4 lagging

Fmin HzFmax HzVmin VoltsVmax Volts

Vnom-max Volts

Fstop Hz

Fstop-CH Hz

Ramp up rates W/sec

Ramp down rates

W/sec

Non linearity %

Measurement error %

Refer to LV EG connection Technical Requirements - Section 4.3.4 & 4.3.5 ramp rate requirement

Refer to LV EG connection Technical Requirements - Section 4.3.4.4 Non-linearity

Testing measurement accuracy

Refer to LV EG connection Technical Requirements - Appendix G

Notes

Refer to LV EG connection Technical Requirements - Appendix F: Sustained operation for frequency variation

Generation ManagementSystem with Generation Management Yes or N/A ?

Ramp rate

Protective function Passive anti-islanding protection

Refer to LV EG connection Technical Requirements - Appendix F: Passive anti-islanding protection

Sustained operation for voltage and frequency variationsRefer to LV EG connection Technical Requirements - Appendix F: Sustained operation for voltage variation

Volt- Watt Response

Refer to LV EG connection Technical Requirements - Appendix F: Volt-Watt response mode

Volt- VAr Response

Refer to LV EG connection Technical Requirements - Appendix F: Volt-VAr response mode

Setpoints (VAr % rated VA)

Refer to LV EG connection Technical Requirements - Appendix F: Volt-VAr response mode

Power Quality Response Mode Voltage balance mode Enabled or Disabled ? ; Default = Disabled

Refer to LV EG connection Technical Requirements - Appendix F: Voltage balance mode, Fixed power factor and reactive power mode and Power factor curve

Fixed power factor mode and reactive power mode

Power factor curve -Cos φ (P)

Site Export Limit Total site export limit to Horizon Power Grid




SCHEDULE 6. NER SIGNOFF *****SAMPLE ONLY: NEW REFERENCE DESIGN**** Horizon Power 18 Brodie Hall Drive Technology Park Bentley, WA, 6102 Your Ref: XXXXXX Our Ref: YYYYYY (if applicable)

DD/MM/YY

Dear Sir/Madam

Subject: Renewable Energy Connection - Project Name, Project Location

Please find attached our submission for the abovementioned project.

This letter is to certify that as a Chartered Professional Engineer and by virtue of my training and experience, the submission documentations issued together with this letter complies with the requirements of the following:

• HPC-9DJ-13-0002-2019 Low Voltage EG Connection Technical Requirements (State latest revision) • Electricity (Licensing) Regulations 1991 • AS/NZS 3000 (State latest revision) • Western Australian Electrical Requirements (State latest revision) • Western Australian Distribution Connections Manual (State latest revision) • AS/NZS 3100 (State latest revision) • AS/NZS 4777 (State latest revision) • AS/NZS 5033 (State latest revision)

In addition, the following schedules have been submitted as part of the application:

• Schedule 1: Compliance Checklist • Schedule 2: System Diagram • Schedule 3: Circuit Diagrams • Schedule 4: Cable Data • Schedule 5: System Parameters

Should you have any queries, please contact the undersigned.

Yours Sincerely,

Chartered Professional Engineer’s Name and NER Number Professional Title Company Name Company Address Contact Detail




*****SAMPLE ONLY: COVER LETTER FOR REUSED REFERENCE DESIGN**** Horizon Power 18 Brodie Hall Drive Technology Park Bentley, WA, 6102 Your Ref: XXXXXX Our Ref: YYYYYY (if applicable)

DD/MM/YY

Dear Sir/Madam

Subject: Renewable Energy Connection - Project Name, Project Location

Please find attached our submission for the abovementioned project. This letter is to declare that the abovementioned project makes use of the reference design for Project (State Project) dated (State Date). An NER accredited chartered professional engineer has checked the reference design and it has been attached to our submission for your consideration.

The abovementioned project does not differ with the NER validated reference design in the key elements described in Section 4.12.1.2of the Technical Requirements.

In addition, the following schedules have been submitted as part of the application:

• Schedule 1: Compliance Checklist • Schedule 2: System Diagram • Schedule 3: Circuit Diagrams • Schedule 4: Cable Data • Schedule 5: System Parameters

Should you have any queries, please contact the undersigned.

Yours Sincerely,

Name Professional Title Company Name Company Address Contact Detail

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