Meta Data

Draft:

Revision of previous policy?:

Effective Start Year:

2020

Scope:

National

Document Type:

Guideline

Economic Sector:

Power

Energy Types:

Power, Renewable, Solar

Issued by:

Ministry of Energy

Source:

Ministry of Energy

File:

Guidelines on Large Scale Solar Photovoltaic Plant Connection to Distribution Grid

Overall Summary:

The Guidelines on Large Scale Solar Photovoltaic Plant Connection to Distribution Grid is applicable to (i). any person or entity who wishes to develop a large scale solar power plant and seeking connection to the transmission and/ distribution electricity network; (ii). the relevant Distribution Service Providers (DSP), whose network is to be connected with the Large Scale Solar (LSS) power plant.

Governance

National policy structure:

5. The key principles of LSS framework shall be as follows: i) The participant of the LSS program must be of a local company of which the Bruneian equity interest in such local company is at least 30% or a consortium of legal entities which includes a minimum of one local company and which has Bruneian equity interest in the consortium of at least 30%; ii) The connection to the electricity network, whether to the Transmission Network or Distribution Network, shall be based on technical criteria and evaluation through a comprehensive power system study; iii) The PPA shall be based on take and pay, energy only under Build, Own and Operate (BOO) concession; iv) The PPA duration is 25 years with fixed energy price throughout; v) The offers by the Shortlisted Tenderers shall be based on the optimum output, final yield and specific yield of the proposed LSS power plant in accordance with the design and technology used. vi) The LSS developer shall declare the plant’s energy production for 25 years. In the PPA, the LSS developer is entitled to be paid the Energy Rate up to the LSS power plant’s Maximum Annual Allowable Quantity (MAAQ).

Full Document Text

NOTE: Some content may not display correctly, including tables and figures. See PDF for full details.

ELECTRICITY ORDER 2017

GUIDELINES ON LARGE SCALE SOLAR PHOTOVOLTAIC PLANT CONNECTION TO DISTRIBUTION GRID

In exercise the power conferred by Part 3 of the Electricity Order 2017, the Authority issues the following guidelines:

Citation and Commencement

These Guidelines may be cited as the Guidelines on Large Scale Solar Photovoltaic Plants Connection to the Distribution Grid.
These Guidelines shall come into effect on the issued date and will be revised as deemed necessary with a new revised issuance date.

Application of these Guidelines

3. These Guidelines is applicable to

any person or entity who wishes to develop a large scale solar power plant and seeking connection to the transmission and/ distribution electricity network;
the relevant Distribution Service Providers (DSP), whose network is to be connected with the Large Scale Solar (LSS) power plant;

Interpretations

4. In these Guidelines, the term used have the same meaning as in the Electricity Order 2017, regulation or codes made under it. In addition, the following words and expressions shall have the meanings assigned to them.

Term	Definition
Authority	Autoriti Elektrik Negara Brunei Darussalam (AENBD);
Commercial Operation Date (COD)	means the date on which all relevant conditions precedent under the Power Purchase Agreement (PPA) have been satisfied or waived;
Directly Connected Customers	as defined in the National Grid Code;
Distribution Network	as defined in the National Grid Code;
Energy rate	means the approved rate or any other rate as may be adjusted in accordance with the terms of the PPA;
Facility	means a solar photovoltaic generating facility and its ancillary equipment;
Grid Owner	means the party that owns the high voltage Transmission or Distribution Network and is responsible for maintaining adequate Grid System capacity in accordance with the provisions of the National Grid Code;

Term	Definition
Grid System	means the Transmission or Distribution Network with directly connected generating unit including Directly Connected Customers;
Interconnecti on Point	means the demarcation line for ownership and maintenance;
Large Scale Solar (LSS)	means any solar photovoltaic plant connected to either the Transmission Network or Distribution Network;
National Grid Code	means the National Grid Code for Negara Brunei Darussalam;
Point of Common Coupling (PCC)	means the point on the Transmission or Distribution Network which is electrically closest to the user installation at which either demands (loads) are, or may be connected;
Power Purchase Agreement (PPA)	means agreement between Transmission or Distribution Service Provider and LSS Developers relating to the financial and technical conditions for the purchase of the energy output and technical conditions relating to connection and performance on the Grid System;
Shortlisted Tenderer	means tenderer who is shortlisted to comply with conditions imposed and to finalize the project documents;
SPP Interconnectio n Facility (IF)	means the new 11kV substation owned by a LSS developer as further described in the PPA to enable LSS developer to deliver solar PV energy from the Facility to the Grid System;

Term

Definition

SPP

Interconnector

means the transmission or distribution line(s) or underground cable(s) (including any associated facilities) that interconnect the SPP

Interconnection Facility and Transmission or

Distribution Service Provider’s

Interconnection Facility;

Successful

Tenderer

means the Shortlisted Tenderer who is issued a letter of award or notice of compliance upon execution of the Project Document;

Distribution

Service

Provider’s

Interconnection

Facility (DSP IF)

Facility

means the existing DSP’s substation (including but not limited to any extension works required to be completed by the LSS developer at the DSP’s substation) or a new switching station to be completed by the LSS developer;

Distribution

Network

The portion of the electrical Grid operated at voltages of 11kV and under - as defined in the

National Grid Code;

Key Principles of LSS Framework

5. The key principles of LSS framework shall be as follows:

i) The participant of the LSS program must be of a local company of which the Bruneian equity interest in such local company is at least 30% or a consortium of legal entities which includes a minimum of one local company and which has Bruneian equity interest in the consortium of at least 30%;

ii) The connection to the electricity network, whether to the Transmission Network or Distribution Network, shall be based on technical criteria and evaluation through a comprehensive power system study;

iii) The PPA shall be based on take and pay, energy only under

Build, Own and Operate (BOO) concession; iv) The PPA duration is 25 years with fixed energy price throughout;

v) The offers by the Shortlisted Tenderers shall be based on the optimum output, final yield and specific yield of the proposed LSS power plant in accordance with the design and technology used.

vi) The LSS developer shall declare the plant’s energy production for 25 years. In the PPA, the LSS developer is entitled to be paid the Energy Rate up to the LSS power plant’s Maximum Annual Allowable Quantity (MAAQ).

Potential Connection Points (Nodal Points)

6. Potential connection points (nodal points) to the electricity Transmission and Distribution Networks to be identified, to facilitate prospective tenderers. Any alternative connection point may be proposed but its approval is up to the Distribution Service Provider. All costs associated with the connection of LSS power plants, shall be borne by the LSS developer. The demarcation of ownership of the plant and system is as depicted in Figure 1, Figure 2 and Figure 3.

Responsibility of the LSS developer

7. The LSS developer is fully responsible to:

obtain right of way (ROW) and permits from relevant local authorities required for the construction of the Facility, SPP IF, SPP Interconnector, DSP IF and network reinforcement up to the Point of Common Coupling as Figure 1, Figure 2 and Figure 3; and
design, construct, test, commission and complete the LSS power plant.

Figure 1: Illustration of Asset Demarcation

Figure 2: Illustration of Asset Demarcation

Figure 3: Illustration of Asset Demarcation

Award of the Project

8. Letter of acceptance of offer or notice of terms and conditions for development of project would be issued to the Shortlisted Tenderers, and the Shortlisted Tenderers is to finalise the PPA with the Transmission Service Provider or Distribution Service Provider.

Upon satisfaction of the terms and conditions in the letter of acceptance of offer or notice of terms and conditions, a letter of award or notice of compliance to the Successful Tenderer and the Successful Tenderer must fulfill all Conditions Precedents (CPs) under the PPA, particularly on the submission of certified and executed site agreement.

Critical Milestones to Commercial Operation Date (COD)

9. As shown in Figure 4 below, the critical milestones for successful completion of LSS power plant shall take place prior to COD.

Licensing Requirement

10. All LSS power plants shall be licensed as per Part 3 Section 5(1) and

(2) of the Electricity Order 2017.

Amendment and Variation

11. This Guidelines at any time, may be updated, modified or revoked as deemed necessary.

APPENDIX A

Technical Specification for Distribution-Connected LSS

Table of Contents

Abbreviations .................................................................................................................... 12

Glossary of Terms .............................................................................................................. 13

Introduction ........................................................................................................... 18
Scope and Limitation...............................................................................................18
Connection to the Grid Distribution System ............................................................19

3.1 Background .................................................................................................... 19

3.2 Connection Voltage Level ...................................................................................... 19

3.3 Penetration Limit ..............................................................................................19

3.4 Nodal Points .....................................................................................................19

3.5 Connection Schemes ........................................................................................20

3.6 Scope of Interconnection Facilities & Asset Demarcation………………………… 21

Technical Requirements ........................................................................................ 23

4.1 General .......................................................................................................... 23

4.1.1 Voltage range ........................................................................................... 23

4.1.2 Voltage fluctuation ................................................................................... 23

4.1.3 Frequency ................................................................................................ 23

4.1.4 Current Harmonics ................................................................................. 24

4.1.5 Voltage Fluctuation and Harmonics ......................................................... 24

4.1.6 DC injection ................................................................................................. 25

4.1.7 Power factor ............................................................................................ 25

4.1.8 Transient Over voltages ........................................................................... 26

4.1.9 System fault level ..................................................................................... 26

4.1.10 Synchronisation ...................................................................................... 27

4.1.11 Inverter ............................................................................................... 27

4.1.12 Standard compliance .............................................................................. 27

4.2 Network Support ........................................................................................... 27

4.2.1 Low Voltage Ride Thru ............................................................................ 28

4.2.2 Frequency disturbance ........................................................................... 28

4.2.3 Power output management ................................................................. 29

4.2.4 Reactive power ........................................................................................ 29

4.2.5 Droop curve ............................................................................................ 30

4.2.6 Power Ramping ....................................................................................... 30

4.3 Protection Requirements ............................................................................... 31

4.3.1 Connection point feeder protection at DSP .............................................. 31

4.3.2 Feeder requirements at LSS plant ........................................................... 31

4.3.3 Fault clearing time .................................................................................. 32

4.3.4 Interlocking of the interconnection feeder ............................................... 32

4.3.5 Protection equipment .............................................................................. 32

4.3.6 Protection coordination study ................................................................. 33

4.3.7 Anti islanding ........................................................................................ 33

4.3.8 Reconnection time .................................................................................. 34

4.3.9 Earthing scheme ..................................................................................... 34

4.4 Meteorological Monitoring Facilities (MMF) and Pyranometer ......................... 34

4.5 Operational Requirements ............................................................................. 35

4.5.1 Preparation of Interconnection Operation Manual (IOM) .......................... 35

4.5.2 Contingencies .............................................................................................. 35

4.5.3 Declared Annual Quantity (DAQ) ............................................................. 36

4.6 SCADA ..................................................................................................................... 36

4.7 Ownership and Boundaries ........................................................................... 36

4.7.1 Boundaries ............................................................................................. 37

4.7.2 Transfer of interconnection facilities ....................................................... 37

4.7.3 Defects in interconnection facilities ......................................................... 38

Metering .............................................................................................................. 38

5.1 General ......................................................................................................... 38

5.2 Energy Meter ................................................................................................. 39

5.3 Metering Point ............................................................................................... 39

5.4 Communication Signal ........................................................................................ 39

5.5 Metering Voltage Transformer (For 11 kV) ...................................................... 39

| Guidelines on Large Scale Solar PV Plant connection to Distribution Grid

5.6 Metering Current Transformer (For ^{^[1]} kV) ..................................................... 40

5.7 Meter Application and Approval ..................................................................... 40

5.8 Meter Reading ............................................................................................... 41

5.9 Metering Panel/Cubicle ....................................................................................... 41

Testing and Commissioning for IOD ..................................................................... 41

6.1 General ......................................................................................................... 41

6.2 Interconnection Operation Manual (IOM) ....................................................... 42

6.3 Testing for Interconnection Facilities ............................................................. 42

6.4 Commissioning Tests for IOD .............................................................................. 43

6.5 Power Quality Measurements ........................................................................ 43

6.5.1 Pre/Post Initial Operation Date (IOD) ..................................................... 43

6.5.2 Permanent Power Quality Measurements ............................................... 44

Commercial Operation Date (COD) ....................................................................... 45

7.1 Verification for COD ............................................................................................ 45

7.2 Confirmation for COD .................................................................................... 46

Safety and Performance Sustainability Requirements ...................................... 46

ATTACHMENT ........................................................................................................................ 47

ATTACHMENT A : Smart Inverter Functions ........................................................................... 47

References : ........................................................................................................................... 51

Abbreviations

This section describes a list of abbreviations used in this document.

Abbreviations	Description
AC	Alternating Current
AVQC	Automatic Voltage and Reactive Power Control
BOO	Build, Own and Operate
COD	Commercial Operation Date
CT	Current Transformer
DAQ	Declared Annual Quantity (in MWh) of Solar PV energy for each Contract year which shall not exceed the MAAQ
DSP	Distribution Service Provider
GIS	Gas Insulated Switchgear
IF	Interconnection Facility
IOD	Initial Operation Date
kV	Kilo-Volt
LSS	Large Scale Solar
MAAQ	Maximum Annual Allowable Quantity (in kWh)
MW	Mega-Watt
NGC	National Grid Code
NEO	Net Energy Output (in kWh)
PCC	Point of Common Coupling
PPA	Power Purchase Agreement
PV	Photovoltaic

Glossary of Terms

Abbreviations	Description
RTU	Remote Terminal Unit
SCADA	Supervisory Control and Data Acquisition
THDI	Total Harmonic Distortion Current
VCB	Vacuum Circuit Breaker
VT	Voltage Transformer

This section describes a list of terms used in this document.

Term	Definition
Anti-Islanding	During loss of mains, the inverter should cease to operate in islanded mode. Inverter should be equipped with anti-islanding protection;
Commercial Operation Date	Means the date at which all relevant conditions precedent under the PPA have been satisfied or waived;
Connection Point	Means the point of common coupling where LSS is connected to the distribution system;
Contingency	Under contingency condition, when one or more circuit elements are on outage, scheduled or non-scheduled;
Contracted Capacity	Means the capacity of solar photovoltaic energy to be generated and delivered to the Grid system at the interconnection point from the facility for each contract year;

Term	Definition
Contract Year	Means, the date on which begins the Commercial Operation Date of the Increment and ends on December 31 of the year in which the Commercial Operation Date of the Increment occurs, each subsequent period during the Term which begins January 1 and ends on December 31 of the same year and the period of twelve (12) months or less which begins on January 1 and ends on the last day of the PPA Term;
Distribution Service Provider	Means distribution grid owner, operator and maintains the distribution grid appropriately;
Distribution Network	The system consisting of electric lines which are owned or operated by a Distribution Service Provider (and used for the distribution of electricity from Grid Supply Points or Generating Units or other entry points to the point of delivery to Customers. “Distribution electricity network” means a system or part of a system at nominal voltage of less than 11kV of electric lines or cables, substations and associated equipment and buildings for transporting electricity to any person;

Term	Definition
Distribution System	The system of electric lines with voltage levels below 66 kV, within the Area of Supply owned or operated by the DSP, for distribution of electricity from Grid Supply Points or Generating Units or other entry points to the point of delivery to Customers and includes any electrical plant and meters owned or operated by the DSP in connection with the distribution of electricity;
Demand or Load	Means demand of MW/kW and MVar/kVar of electricity (i.e. both active power and reactive power), unless otherwise stated;
Facility	means a solar photovoltaic energy generating facility, its ancillary equipment and facilities;
Interconnection Facility or IF	The components that interconnect the LSS and the distribution network. This includes the substation at the LSS, overhead lines or underground cables where the connection to the distribution network is made;
Initial Operation Date or IOD	The date on which the LSS installation first delivers Net Electrical Output to the DSP network for testing purposes;
Inverter	A machine, device, or system that changes DC power to AC power;

Term	Definition
Islanding	A condition in which a portion of the utility system that contains both load and distributed resources remains energized while isolated from the remainder of the utility system;
Large Scale Solar or LSS	Any solar PV Plant connected to either transmission or distribution network in Brunei Darussalam;
MAAQ	means the maximum annual allowable quantity (in kWh) determined as a product of the Established Capacity, the capacity factor and the number of hours in a year;
Medium Voltage	A voltage equal to or exceeding 1kV but not exceeding 50kV;
National Grid Code	National Grid Code is a document containing a set of technical rules and procedures that facilitate coordinated planning, design, development, and coordinated operation of the Grid System;
Net Energy Output or NEO	Means for any period, the amount of solar energy generated and delivered to the DSP at the metering point;
Power Purchase Agreement or PPA	Agreements between the Distribution Service Provider (DSP) and LSS Developer relating to the financial and technical conditions relating to the purchase of LSS output and technical conditions relating to its connection to and performance on the Grid System;

Term	Definition
Prudent Utility Practice	The exercise of such degree of skill, diligence, prudence and foresight which would reasonably and ordinarily be expected from a skilled and experienced operator engaged in the same type of undertaking under the same or similar circumstances;
Type Test	Test of one or more devices made to a certain design to demonstrate that the design meets certain specifications;
Prudent Utility Practice	The exercise of such degree of skill, diligence, prudence and foresight which would reasonably and ordinarily be expected from a skilled and experienced operator engaged in the same type of undertaking under the same or similar circumstances;
Type Test	Test of one or more devices made to a certain design to demonstrate that the design meets certain specifications;
Power Factor	Power factor (PF) is calculated by dividing the Real Power, P, in the W unit by the Apparent Power, S, in the VA unit.

17 | Guidelines on Large Scale Solar PV Plant connection to Distribution Grid

1. Introduction

This guideline has been prepared as guidance only to facilitate prospective LSS developers seeking connection to the DSP’s Distribution Network.

MW described in this guideline refers to the AC side of the LSS plant.

2. Scope and Limitation

Large Scale Solar (LSS) PV Plants described in this document refer to those connected to the distribution network at 11kV.

The Guidelines are not intended to cover all required authorizations, permits and/or licenses which the LSS developer is required to obtain from the relevant bodies and/or authorities for the purpose of the development of LSS.

The LSS developer shall, at its own costs, be fully responsible for the inspection, examination, checking and verifying the accuracy, correctness and completeness of any and all data as to the site and its surroundings and the nature of the climatic, geological, soil and general conditions of the site as well as the potential nodes as identified by the DSP in order to meet the requirements of the Power Purchase Agreement. The LSS developer is also at its own costs, be responsible to obtain, maintain and renew all authorizations, permits and licenses necessary for it to develop the LSS and to otherwise perform its obligations under the Power Purchase Agreement or any other Project Documents and comply with all conditions and requirements as may be imposed or prescribed by any relevant bodies and/or authorities which has jurisdiction over the development of LSS.

Each LSS developer shall accept full responsibility for conducting an independent analysis of the accuracy, correctness and completeness of any and/ all data; and for gathering and presenting all necessary information.

3. Connection to the Grid Distribution System

3.1 Background

The connection of the LSS plant is to be made only at the existing DSP’s substation. The evaluation of connection requirements is subject to the terms and requirements of the DSP and the National Grid Code.

The limiting factors at the substation such as fault level, transformer daytime loading are important for the assessment of the connected generation capacity. Impact such as substation loading and voltage rise due to power generation could determine the limit of capacity allowed for the LSS power generation.

3.2 Connection Voltage Level

The LSS plant can be connected to the 11kV and 415V distribution voltage level.

3.3 Penetration Limit

Distribution network is operated in lateral feeders with off-point located strategically. To cater for the n-1 contingency requirement, feeders are loaded at only 50% of its thermal capacity. Therefore, to determine the capacity of connected LSS, the 50% feeder loading is to be adopted.

Output from LSS connected to distribution network is to be consumed locally. Therefore, the penetration limit of LSS to a substation is limited to the daytime loading level of the substation. The loading level is to be determined by the DSP based on its record of recent substation demand trend. Estimation of future demand growth shall not be considered.

3.4 Nodal Points

The connection to the distribution network is to be done only at the existing substations owned by the DSP.

For the purpose of facilitating the potential LSS developer, nodal points have to be identified for connection to distribution network. The nodal points were selected based on the following considerations:

a) Fault level

b) Adequate daytime trough load

Other possible constraints include the availability of space for the new switchgear including the associated control panel and the metering room.

The potential nodal points as identified shall be used as guidance only as actual feasibility study depends on the findings of the PSS. The DSP has the rights to review and update the potential nodal points.

3.5 Connection Schemes

The interconnection feeder shall be using circuit breaker which shall be provided by the LSS developer. All costs including any modification/extension to the existing substation in order to accommodate connection of LSS to the grid shall be borne by the LSS developer.

Typical scope of works for the interconnection feeder is described (not limited to) in Table 1. However, the actual works shall be determined based on the actual site requirements.

Table 1: Typical Scope of Works for Upgrading

	Upgrading at substation		Upgrading at Main Intake Station
  	Replace existing Ring Main Unit (RMU) to VCB Remote Control Box (RCB) Direct Current(DC)		Extension to existing switchgears (VCB/GIS) Control Relay Panel (CRP)
 		system Building works as necessary Meter room	  	SCADA/RTU Arc protection (where applicable) Building works as necessary
				Meter room

Figure 5: Upgrading of the Switchgears at PCC

3.6 Scope of Interconnection Facilities & Asset Demarcation

This section describes the feature of the interconnection feeder which connects the LSS plant to the DSP substation. The connecting cable consists of underground or aerial cable to carry only the generated power and fibre optics cable for differential protection relay and interlocking communications.

All costs including any modification or extension to the existing substation in order to accommodate connection of LSS to the grid shall be borne by the LSS developer.

The LSS developer is responsible in acquiring the right of way for the underground or aerial cable route and any related land acquisitions.

Figure 6: DSP-LSS Interconnection Feeder Scheme

An LSS developer scope of works (not limited to) are to include the following:

(i) Supply of interconnection facilities for LSS and DSP side (refer to Figure 6)

(ii) The interconnection works shall be designed, built, owned, operated and maintained by the LSS developer

(iii) All works for interconnection is under the responsibility of LSS developer

(iv) Interconnecting power cable capacity and fibre optics based on PSS

(v) The equipment is to match existing or DSP’s required specifications

(vi) Protection scheme is to meet DSP’s requirement

(vii) Energy meters and dedicated metering room

(viii) Interlocking scheme

(ix) SCADA requirements

(x) Anti-islanding shall be provided at the LSS plant

(xi) Install and maintain PQ Recorder at LSS plant

(xii) Submission of drawings and manuals

4. Technical Requirements

4.1 General

The technical requirements outlined in this guidelines are to ensure that the connection of LSS to the distribution system is harmonised with the existing system characteristics.

4.1.1 Voltage range

Distribution network voltage fluctuates in response to the feeder length and the load level. Table 2 describes the limits to be complied for the planning of the interconnection.

Table 2: Steady State Voltage Limits

Nominal Voltage	Steady state voltage limits
230V, 400V	+10%, -6%
11kV	±5%

4.1.2 Voltage fluctuation

The maximum voltage fluctuation range allowed due to varying solar radiation is 6%. This requirement differs from that for voltage flicker.

4.1.3 Frequency

LSS developer shall maintain plant frequency to operate in synchronism with distribution system. Nominal system frequency is

50 Hz with normal range of ±1% which is between 49.5Hz and 50.5Hz. Grid frequency may temporarily deviate due to large changes in load, the tripping of a generator, or system faults. Limits for these various conditions are as follows:

- Normal Operating Conditions: 49.5 Hz to 50.5 Hz

- During System Stress: 49.0 Hz to 51.0 Hz

- Maximum deviation during faults: 48.75 Hz to 51.25 Hz

- Tripping values for generators 51.5 Hz or above and 47.5 Hz

or below

4.1.4 Current Harmonics

Total Harmonic Distortion Current Distortion (THD) shall be <5 % at inverter rated output. The point of measurement is at the Point of Common Coupling.

Each individual harmonic shall be limited to the percentages listed in table below (Current distortion limits referenced to IEC 617272003 Table 1). Even harmonics in these ranges shall be less than 25% of the lower odd harmonic limits listed.

Table 3: Distortion limit for Odd Harmonics

Odd harmonics	Distortion limit (%)
3 – 9	< 4.0
11 – 15	< 2.0
17 – 21	< 1.5
23 – 33	< 0.6

Table 4: Distortion Limit for Even Harmonics

Even harmonics	Distortion limit (%)
2 – 8	< 1.0
10 – 32	< 0.5

4.1.5 Voltage Fluctuation and Harmonics

Table 5 highlights the acceptable permissible values for voltage fluctuation and harmonics. The point of measurement is at the Connection Point normally at the DSP substation.

Table 5: Acceptable Permissible Value at PCC for Voltage

Fluctuation and Harmonics

Type Of Disturbance

Indices

Acceptable permissible values at

Connection

Point

Reference

Document

Voltage Flicker

Absolute

Short

Term

Flicker

Severity

(Pst)

1.0 (at 132kV and

below)

UK’s Engineering

Recommendation

P28

Absolute

Long Term

Flicker

Severity

(Plt)

0.8 (at 132kV and

below)

Harmonic

Distortion

Total

Harmonic

Distortion Voltage

(THDV) %

4 % at 11kV

Engineering

Recommendation

ER G5/4

Voltage Unbalance

Negative

Phase

Sequence

Voltage %

2% for 1 minute

UK’s Engineering

Recommendation

P29

4.1.6 DC injection

LSS plant shall not inject DC current more than 1% of the rated inverter output current under any operation condition.

4.1.7 Power factor

Each External party is required to ensure that its installation has satisfactory power factor correction to ensure that, the power factor as measured at the Connection point and should use reasonable endeavors to maintain its average power factor between Unity and 0.9 lagging.

Figure 7: Voltage versus power factor curve

4.1.8 Transient Over voltages

Typical Basic Impulse Insulation Levels (BIL) of the distribution system is as indicated in Table 7. The LSS Plant and its apparatus shall be compatible with the insulation levels of the distribution system.

Table 6: Basic Impulse Insulation Levels (BIL)

System Voltage (kV)	BIL (kV)
11	75

4.1.9 System Fault Level

Table 7 below shows the rated equipment to be used to withstand the maximum sub- transient three phase symmetrical short circuit fault levels.

Table 7: Short Circuit Withstand Rating for Power Equipment

Nominal

Voltage [kV]

Rated

Voltage

[kV]

Fault

Current

[kA]

20/25

4.1.10 Synchronization

Synchronization devices shall be provided and maintained by the LSS developer. During operation, synchronization is at the LSS plant side by matching with the distribution system parameters as mentioned below:

(i) Interlocking logics are satisfied

(ii) Frequency difference <0.2 Hz

(iii) Voltage magnitude difference < 10%

(iv) Voltage angle difference < 10 degrees

Inverter shall be capable of synchronizing with the grid automatically within the specified reconnection time.

4.1.11 Inverter

The LSS plant shall use type of inverters that have advanced or smart inverter functions. The inverter shall comply with the technical requirement for connection to distribution network as required by the DSP. Smart inverters are PV inverters that stay connected and provide additional functions to help actively support the grid - mainly voltage and frequency. Traditional inverters simply disconnected when the grid voltage or frequency went out of range. Broadly, smart inverters provide some additional benefit to the grid beyond simply converting direct-current (DC) electricity to alternating current (AC) from PV systems. The smart inverter functions are outlined in Attachment A.

4.1.12 Standard compliance

The LSS plant and its interconnection shall comply with the standards set as requirement and also to comply with the National Grid Code.

4.2 Network Support

The LSS plant shall provide support to the network to ensure that the system is stable by:

(i) To not disconnect

(ii) To support network voltage by feeding reactive power

4.2.1 Low Voltage Ride Thru

During disturbance at transmission system, distribution system will experience temporary low voltage or sag. The LSS plant is expected to continuously operate during distribution system voltage fluctuation as shown in Figure 8 below.

Figure 8.: Distribution system voltage fluctuation

4.2.2 Frequency disturbance

The LSS plant is expected to be uninterrupted within the frequency range of 49.5 to 50.5Hz.

During frequency disturbance, when the frequency increases more than 50.5Hz, the LSS plant shall reduce its power output as shown in Figure 9.

4.2.3 Power output management

The LSS plant shall have the capability to manage its power generation:-

The LSS plant shall be able to reduce its power output or disconnect from the distribution system during system contingencies.
LSS plant shall reduce its generation output to avoid voltage rise above the limit.
The LSS developer shall monitor and ensure that the power generation of the plant does not exceed the contracted capacity.
The inverter shall have the capability to perform active/reactive power control and/or voltage control for voltage regulation.

4.2.4 Reactive power

The LSS plant shall be able to deliver the reactive power requirement at the connection point as shown in Figure 10. Full range of reactive power 0.85 lagging to 0.9 leading shall be achieved at 20% output.

Figure 10: Active power output versus power factor curve

4.2.5 Droop curve

The LSS plant shall be fitted with a droop controller or equivalent control device to provide frequency response under normal operational conditions as in 4.1.3.

4.2.6 Power Ramping

The LSS plant shall be able to automatically and manually control the ramp rate and limit the real power. This is to ensure stability of the system and prevent any power surge caused by sudden injection by the Facility.

The LSS plant shall be capable to control the increase and decrease of power delivery within ramp rate of 15% per minute of rated capacity.

The Facility shall be able to regulate the ramp rate of the active power output for the following scenarios:

Dispatch Instruction (if required);
Normal load variation;
Facility startup (black start); and
Facility shutdown.

4.3 Protection Requirements

The LSS plant protection scheme is under the LSS developer’s responsibility and the LSS developer shall declare the protection scheme and settings to the DSP.

4.3.1 Connection point feeder protection at DSP.

The protection interfacing requirements are as follows:

Unit Protection (Current Differential)
OCEF / Non Directional OCEF
Interlocking scheme
Reverse Power Relay

Where applicable, the following protection schemes may be required:

(i) Arc protection

(ii) Busbar protection

(iii) Automatic transfer scheme

4.3.2 Feeder requirements at LSS plant

The LSS feeder shall be equipped with the following equipment:

Current Differential Relay
PQ recorder

The PQ recorder shall measure THDI, voltage fluctuation and flicker. Data storage capacity for the PQ recorder is to last at least for 1 month. The sampling rate shall be at least 128 samples per cycle.

4.3.3 Fault clearing time

The fault clearing time for 11kV network is as depicted in Table 8.

Table 8: Fault Clearing Time

Type of fault	11kV
Substation & transformer faults	150ms
Overhead line & cable faults	600ms

4.3.4 Interlocking of the interconnection feeder

The interlocking facilities shall operate in the following manner

(subject to the approval of the DSP), referring to Figure 10 below.

A open – B to open
B close position – A cannot close
A open position – B cannot close
Earth Switch (ES) B ON – A cannot close

Figure 11: Interlocking of the interconnection feeder with DSP

4.3.5 Protection equipment

The protection relay and PQR equipment to be used is subject to the approval by DSP.

4.3.6 Protection coordination study

LSS developer shall carry out the internal protection coordination to mitigate internal and external fault.

For any internal fault, the LSS plant shall not cause problems to the utility system and its customers. The failure of the LSS plant equipment includes:

Failure of protection equipment
Failure of control equipment
Loss of control power
Interconnection power and fibre optics cables

For any distribution network fault outside the LSS plant, the LSS plant shall be protected from any damaging effect. LSS plant shall be disconnected from the grid during any of above the conditions.

4.3.7 Anti-islanding

During loss of mains, the inverter shall cease to operate in islanded mode. The anti-islanding protection is required to mitigate the following events: • Safety

Power quality
Inverter technical limit

4.3.7.1 Anti-islanding detection

Inverters shall have the following anti-islanding capabilities:

(i) Under Voltage

(ii) Over Voltage

(iii) Under Frequency

(iv) Over Frequency

(v) 1 additional active or passive anti-islanding detection

4.3.7.2 Isolation time

Upon detection of the loss of mains, LSS plant shall be isolated within the time as in Table 8.

4.3.8 Reconnection time

The reconnection time of the LSS plant to the distribution network shall be more than 5 minutes after DSP connection has been stabilized.

4.3.9 Earthing scheme

The LSS plant earthing scheme shall not cause mal-operation to the DSP protection scheme.

The zero sequence components between the DSP network and LSS plant shall be isolated. The LSS plant step up transformer(s) shall have delta (∆) configuration on DSP side as illustrated in Figure 12 to ensure the plant does not contribute zero sequence current to DSP network during fault.

Figure 12: Step up Transformer Earthing Scheme

4.4 Meteorological Monitoring Facilities (MMF) and Pyranometer

The LSS developer shall provide the following:

(i) Install Meteorological Measuring Facilities (MMF) and pyranometer at the site.

(ii) 1 set (MMF & pyranometer or solar cell sample) per 1MW

(iii) Meteorological station has an independent and backup power source.

(iv) LSS must maintain historical data of readings for throughout the term.

(v) Minimum data resolution: Every 15 minutes.

(vi) Submit meteorological report to the Authority and DSP as and when required

4.5 Operational Requirements

4.5.1 Preparation of Interconnection Operation Manual (IOM)

The documents to be prepared for each interconnection shall address (not limited to) the following:

(i) Interconnection Facilities

(ii) Communication

(iii) Switching Procedures

(iv) Fault Reporting

(v) Outage Program

(vi) System Emergency or Collapse

(vii) Sequence of Operation

(viii) Boundaries and Ownership

4.5.2 Contingencies

During contingency, the LSS plant may be isolated until the system is normalised. Contingencies include scheduled and unscheduled outages:

i.Network upgrading

Maintenance iii. Shutdown iv. Breakdown

4.5.3 Declared Annual Quantity (DAQ)

The LSS developer is required to declare annual output to the Authority and the DSP.

4.6 SCADA

All cost for the SCADA facility is to be borne by the LSS developer including RTU cubicle and associated cards and SCADA ready switchgears. SCADA equipment to be used is subject to the approval by DSP.

The following parameters are required to be made available to the Authority and DSP, for monitoring purpose.

(i) Frequency (Hz)

(ii) Voltage (V)

(iii) Current (A)

(iv) Real Power Energy flow (kW or MW)

(v) Reactive Power Energy flow (kVar or MVar)

(vi) Circuit Breaker status

(vii) Relay indications

All interfacing wirings shall be prepared by the LSS developer with DSP’s supervision.

4.7 Ownership and Boundaries

All equipment which are to be transferred to the DSP is required to comply with the DSP’s specifications. The ownership boundary of the LSS developer is up to and including the cable termination at the Connection Point at DSP Distribution System.

4.7.1 Boundaries

Determinations of boundaries are as shown in Table 9.

Table 9 : Boundaries and Ownership Between DSP and LSS developer

Item	Ownership	Control	Operation	Maintenan ce
	DSP substation
Primary	DSP	DSP	DSP	DSP
Secondary OCEF + RPR CD + communica tion Interlocking	DSP LSS LSS	DSP LSS LSS	DSP LSS LSS	DSP LSS LSS
	LSS substation
Primary	LSS	LSS	LSS	LSS
Secondary OCEF + RPR +CD PQR	LSS LSS	LSS LSS	LSS LSS	LSS LSS

OCEF – Overcurrent Earth Fault, CD – Current Differential, RPR – Reverse Power Relay, PQR – Power Quality Recorder

The LSS developer shall own and be responsible for the costs of operation and maintenance of all installations located within their boundary.

4.7.2 Transfer of interconnection facilities

Upon the completion of the interconnection facilities, the LSS developer shall transfer the interconnection facilities beyond his or its ownership boundary to the DSP and take all necessary actions to transfer to the DSP of all rights, title and interests to the interconnection facilities so that the DSP shall become the owner of such interconnection facilities.

The DSP henceforth shall be responsible for the operation and maintenance of the interconnection facilities.

4.7.3 Defects in interconnection facilities

If the DSP discovers that the interconnection facilities or any part of the IF that has been transferred to it:

(i) Was not designed, constructed, installed and tested in accordance with prudent utility practices; or

(ii) Contains any defect in its design, materials or workmanship

The LSS developer is required, at his or its own cost, make all necessary repairs or replacements so that the interconnection facilities conform to the requirements of prudent utility practices and shall be free from any such defect.

However, the obligation of the LSS developer shall not apply in respect of any non-conformance or defect arising:

(i) From the DSP’s failure to operate and maintain the interconnection facilities in accordance with the operation and maintenance manuals and prudent utility practices;

(ii) From the effects of ordinary wear and tear or erosion or corrosion which such facilities were not designed for; or

(iii) After an initial period of twelve months from the COD, and in respect of any part of such facilities that was repaired or replaced during such IOD, after a period of twelve months from the date of completion of such repair or replacement.

5. Metering

5.1 General

All energy meters used for measuring the import and export of electricity shall comply with DSP’s specifications. DSP shall determine the point at which every supply line shall terminate in any premise in view of ease of accessibility to DSP’s personnel.

The LSS developer is required to provide meter panel according to DSP’s specifications for the installation of meter and their accessories. DSP may change any meter and its accessories or their positions in any premise as deemed necessary at any time for purposes of maintenance and meter reading.

5.2 Energy Meter

The main and check meters are to be installed by DSP to measure the energy import and export. The energy meters shall be procured from DSP. The cost will be inclusive of supply and installation for both meters.

The energy meters shall be mounted on the metering cubicle. The dimension and specifications of the meter cubicle are to comply with the latest DSP electricity supply application or installation guideline or specification. All drawings is to be endorsed by a Professional Engineer.

5.3 Metering Point

Energy meter is to be installed at the connection point in a dedicated meter room at DSP’s substation. The LSS developer is required to provide a Switch Socket Outlet (13 Amps) at the meter room.

5.4 Communication Signal

DSP uses wireless mode of communication between energy meter and DSP data centre. Location of the meter room must have adequate reception of the wireless signal to enable data transmission. LSS developer shall provide signal booster equipment whenever the communication signal is weak.

5.5 Metering Voltage Transformer for 11 kV

The details for the Inductive type VTs is shown in Table 10.

Table 10: Metering Voltage Transformer

Parameters	Description
Ratio	Vs / √3 V 110 / √3V * where Vs is the voltage at metering point
Class	0.5
Burden	100 VA, sharing can be allowed provided separate fusing is provided
Voltage factor	1.9 for 8 hours
Unit	3 nos. for each feeder
Standards	IEC 60044-1 Edition 1.2 2003-02 and IEC 60044-2 Edition 1.2 2003-02

5.6 Metering Current Transformer for 11 kV

The details for the metering current transformer are shown in Table 11.

Table 11: Metering Current Transformer

Parameter	Description
Ratio	Is / 5A * where Is = the primary ratio of the metering CT
Class	Class 0.2
Burden	15 VA
Unit	3 Nos. for each feeder
Standards	IEC 61869-2:2012 and IEC 61869-1:2007

5.7 Meter Application and Approval

The LSS developer is required to liaise with the DSP on the requirements for meter application and approval.

Test certificate and wiring diagram of the current transformers and voltage transformers shall be supplied by LSS developer. The CTs and VTs shall have a valid test certificate from an accredited laboratory.

5.8 Meter Reading

The LSS developer is to read the revenue meter with DSP (joint inspection) on a monthly basis and not later than 7 days after reading the revenue meter, the LSS developer is required to prepare and submit an invoice to DSP for payment.

The LSS developer may at any time submit a written request to the DSP to inspect or test the energy meters. If the meters are found to be defective or inaccurate, both DSP and the LSS developer are to recalculate and agree on the amount payable during the period of inaccuracy. However, if the meter is accurate, the cost for energy meter testing shall be borne by the LSS developer.

5.9 Metering Panel

The meter panel or cubicle shall be designed by LSS developer and endorsed by DSP. LSS developer is to prepare the wiring for the meter and conduct the relevant test as per the DSP requirements.

The LSS developer shall maintain the meter panel or cubicle and its accessories except for the energy meter and test terminal block.

6. Testing and Commissioning for IOD

6.1 General

The LSS developer is to notify DSP in writing once the LSS plant installations and the interconnection facilities is ready to be commissioned. The LSS developer is required to submit all the documents for IOD as the following:

(i) A certificate from a Professional Engineer stating that the interconnection facilities have been designed and constructed in accordance with prudent utility practices.

(ii) Copies of approved as-built drawing of the interconnection facilities

(iii) Copies of IOM approved by DSP

(iv) Test results of the Interconnection Facilities

(v) A copy of metering scheme approval

(vi) Transfer documents for DSP substation and land if applicable

(vii) Electricity Licence from the Autoriti Elektrik Negara Brunei Darussalam (AENBD)

(viii) Approval letters from authorities on right of ways for cable routes

(ix) Written confirmation from DSP on the completion of site work without any outstanding issues

The submission of a complete IOD document shall be made not less than 60 days of the proposed IOD. The commissioning notification shall be issued upon receipt of the complete IOD documents.

6.2 Interconnection Operation Manual (IOM)

The purpose of the IOM is to outline the duties and the responsibilities of both parties at the interconnection between DSP and the LSS plant. The IOM is also to set out the necessary procedures to be followed to ensure safety to the operating personnel and to avoid any damage to the equipment at the interconnection point. The LSS developer shall prepare the IOM for the interconnection and jointly agreed by the DSP.

The IOM has to be completed before the commissioning process could be considered.

6.3 Testing for Interconnection Facilities

Testing shall be carried out during the shutdown stage which involves the connection of the LSS plant to DSP network. Such test includes and not limited to the following:

(i) Electrical protection scheme

(ii) Protection coordination study

(iii) Cable and/or overhead test result

(iv) SCADA

(v) VCB and DC system

All tests is to be carried out by a qualified tester and with a valid calibration certificate.

6.4 Commissioning Tests for IOD

There are 2 levels of testing required:

(i) Inverter compliance tests

(ii) Interconnection compliance tests

The scope of testing during IOD shall cover:

(i) The LSS plant shall cease to energise during loss of mains. Antiislanding test must comply with the following time:

Disconnection time: ≤2s and
Reconnection time: >5min

(ii) Functional tests of all equipment

(iii) Any resetting of factory-set parameters at site requires testing to be redone.

All test results shall be certified by Professional Engineer to be submitted to DSP.

6.5 Power Quality Measurements

6.5.1 Pre/Post Initial Operation Date (IOD)

Power quality measurements are to be done at the point of connection to ascertain the existing power quality before commissioning and after the connection of LSS plant. The recording period shall be 7 days before commissioning to capture the base voltage regulation profile without LSS plant and 7 days after commissioning with the LSS plant connected. The recording interval shall be not less than 10 minutes.

Measurement shall capture the following parameters and not limited to:

(i) Total harmonic distortion (THD) voltage

(ii) Unbalanced voltage

(iii) Flicker voltage

(iv) RMS Voltage

(v) Power Generation (kW)

(vi) Reactive Power (kVAr)

(vii) Power factor

(viii) Energy kWh (daily)

6.5.2 Permanent Power Quality Measurements

The LSS developer shall install a permanent power quality recorder at the LSS circuit breaker and to submit the PQ report as and when requested by DSP.

Measurement shall capture the following parameters and not limited to:

i. Total harmonic distortion (THD) Current and each individual current harmonic ii. Total harmonic distortion (THD) Voltage iii. Unbalanced voltage iv. Flicker voltage

v. RMS Voltage vi. Power Generation (kW) vii. Reactive Power (kVAr) viii. Power factor ix. Energy kWh (daily)

x. Voltage dip and swell events

7. Commercial Operation Date (COD)

7.1 Verification for COD

The verification for COD shall be conducted after IOD and the minimum duration shall be not less than 7 days. The verification tests shall be performed by a Professional Engineer and witnessed by the DSP. The verification test parameters include the following:

(i) Grid Frequency Variation

(ii) Reactive Power Control (voltage control and power factor control modes)

(iii) Grid system voltage variation

(iv) Grid system fault level

(v) Protection System

(vi) Voltage support (AVQC) & Active Power Control

(vii) Equivalent control device to speed governor (Droop curve)

(viii) Frequency MW Response

(ix) Power Quality

(x) Fault ride through (LVRT)

(xi) Power ramping (up and down)

(xii) Inverter functional tests and verifications

The COD verification methods are depicted in Table 12.

Table 12: Interconnection Facility Verification Methods

Test method	Description
Factory test	Valid test certificate/results from the factory
Site test	Electrical and functional tests of the interconnection facility
Site verification	Confirmation against approved drawings or Specification

7.2 Confirmation for COD

The LSS developer is to submit to the Authority and DSP the report for COD confirmation. The report shall consist of:

(i) Verification report

(ii) PQ report

Upon receipt of the reports, the Authority shall issue a letter of confirmation on COD to the LSS developer and DSP to initiate payment.

8. Safety and Performance Sustainability Requirements

The safety requirements to be adopted by the LSS developer and DSP for work or testing at the interconnection facilities shall include the following:

(i) The LSS developer shall provide the as-built single line diagrams of the interconnection facilities at the respective side of the connection point;

(ii) The LSS developer shall have their own safety rules and/ safety instructions which comply with the Electricity Order 2017 and/ or any other law in Brunei Darussalam and prudent utility practices.

(iii) The LSS developer shall designate a competent Licenced Electrical Worker to operate the interconnection facilities within their boundary.

The LSS developer shall at its own cost conduct the testing of LSS plant (including the Interconnection Facility) and thereafter, submit the report of such testing, which report shall be certified by a Professional Engineer, to the Authority and DSP on the 10^th and 15^th year of the contractual Term.

ATTACHMENT

ATTACHMENT A: Smart Inverter Functions

Continuous growth of PV generation puts more challenges on grid infrastructure designed for distribution from centralized energy sources. Advanced or smart inverter functions can help address the grid stability problems posed by high levels of variable distributed generation
Smart inverters are PV inverters that stay connected and provide additional functions to help actively support the grid - mainly voltage and frequency.
Broadly, smart inverters provide some additional benefit to the grid beyond simply converting direct-current (DC) electricity to alternating current (AC) from PV systems. They typically support overall grid reliability by offering the following functions:

Functions

Description

Setting

Anti-islanding

Protection

Automatically disconnect from the grid during power outage within certain duration. The duration is adjustable.

Anti-islanding protection is to ensure inverter does not back-feed a disabled grid

LV:

Disconnect 2sec
Reconnect 2min MV:
Disconnect 2sec
Reconnect 5min

No	Functions	Description	Setting
2	Voltage and Frequency Ride-through Capability	Inverter must meet the mandatory and permissive operation requirements as well as the must trip limits when the AC grid voltage and frequency high or low limits are exceeded.
		Inverters are to support the grid during brief voltage or frequency excursions. This function will help the grid to self-heal from a disturbance.
		During periods of deviations in grid voltage and/or frequency, smart inverters are designed to remain connected to the grid and adjust their output to act as a counterbalance to frequency or voltage changes
3	Ramp Rate Control	The rate of power increase when first ramping (start ramp) and subsequent increases in offsetting or selling (normal ramp)	Does not exceed 15% of rated capacity per minute.
		To help smooth transitions from one output level to the next. Supports grid by ramping up slowly giving the grid time to adjust to the PV energy coming back online.	Applicable for LSS capacity of 5MW and above

Functions

Description

Setting

Reactive Power

Control

Functions

Inverter is able to supply or absorb reactive power to/from the grid to maintain stable grid voltage when fluctuations are prevalent.

Variable Power Factor provides active voltage stabilization:

Grid voltage nominal, purely active power
Grid voltage high, add ‘inductive’ reactive power
Grid voltage low, add ‘capacitive’ reactive power Adjusting VARs keeps grid voltage from oscillating; acts like a shock absorber

The reactive power control can be achieved using 3 main controls:

(a) Dynamic Volt/VAr Mode (voltage control)

(b) Fixed power factor (pf control)

Voltage range:

(MV-11kV)

+ 5%

(LV- 230V & 400V)

-6% +10%

Power Factor range:

0.85 lagging to 0.9

leading

N0	Functions	Description	Setting
5.	Active Power Control Functions Frequency- Watt (Droop Curve) and Volt-Watt	Support grid frequency and voltage by changing inverter wattage output. Help to stable the grid during an under/over frequency and voltage event by controlling the real output of the solar system. Grid frequency/voltage nominal, inverter at max output Grid frequency/voltage high, inverter curtails power Grid frequency/voltage low, inverter increases power	Frequency range: 47Hz to 50.5Hz Voltage range: (MV-11kV) + 5% (LV- 230V & 400V) -6% +10%
6.	Data log/Memory card for event logs	Capture profile of networks parameters – Voltage, Current, Frequency, Power (active & reactive), power factors and events log. The data log can be used for troubleshooting and monitoring purposes.
7.	Remote monitoring and configurability	Able to control remotely using SCADA system (for capacity 1MW and above)

Technical Specifications for Distribution-Connected LSS

References:

(i) Guidelines On Large Scale Solar Photovoltaic Plant for Connection to Electricity Networks by Suruhanjaya Tenaga

(ii) TNB Technical Guidebook on Grid-interconnection of Photovoltaic Power

Generation System to LV and MV Networks

(iii) Electricity Order 2017

(iv) National Grid Code

51 | Guidelines on Large Scale Solar PV Plant connection to distribution grid

Technical Specifications for Distribution-Connected LSS

Disclaimer:

The Appendix A of these Guidelines specifies the technical specifications for distribution-connected LSS that has been prepared for guidance and information purposes only. It does not contain comprehensive information required in designing the LSS facilities. Whilst all reasonable care has been taken in the preparation of the Guidelines, the Authority does not make any representation, warranty or undertaking, expressed or implied, in or in relation to the completeness and or accuracy of information contained in this Guidelines. Therefore, the Authority disclaims all or any responsibility whatsoever to anyone for information contained in the Guidelines or for any representation or statement herein, whether expressed or implied, or for any responses given in response to any queries on or in relation to the Guidelines. All such persons expressly disavow any obligation or duty (whether in contract, tort or otherwise) to any prospective LSS developer and disclaim any and all liabilities based on or relating to any such information or representations or warranties (expressed or implied) contained in, or errors or omissions from, the Guidelines or based on or relating to the use of the Guidelines or any other written or oral communication transmitted to or information provided to or otherwise acquired by a prospective LSS developer.

A prospective LSS developer shall be solely responsible for the interpretation of the information provided to or otherwise acquired by the prospective LSS developer. The prospective LSS developer certifies that it understands, accepts and agrees to the disclaimer on this page. Nothing contained in any other provision of this Guidelines, nor any statement made orally or in writing by any person or party have the effect of negating or superseding any of the disclaimers on this page.

52 | Guidelines on Large Scale Solar PV Plant connection to distribution grid

[1] | Guidelines on Large Scale Solar PV Plant connection to Distribution Grid