| 1 Flexible Plug and Play - UK Power Networks

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Flexible Plug and PlayA demonstration of the technical characteristicsof the Flexible Plug and Play solution - SDRC 9.4

September 2013

Definitions

Active Network Management (ANM) Autonomous, software-based control system that monitors grid conditions and issues

instructions to distributed generators or other field devices in order to maintain the

distribution network within operating limits.

Automatic Voltage Control (AVC) Substation level system that is used to maintain the substation voltage at a constant

value and within the statutory limits.

Combined Heat and Power (CHP) Co-generation or use of power plant to simultaneously generate electricity and

useful heat.

Communications platform The communications platform installed and commissioned in the FPP trial in March

2013. It is based on the Radio Frequency wireless mesh technology.

CDM Construction, Design and Management 2007: regulations used in the construction

industry in UK.

DigSILENT Manufacturer of PowerFactory – a power systems modelling tool used by

UK Power Networks.

Distributed Generation (DG) Electricity generation connected to the distribution network.

Distributed Network Protocol (DNP3) Communication protocol widely used currently in the utilities industry.

Dynamic line rating System for calculating real-time ratings of overhead lines based on actual

weather data.

EPN Eastern Power Networks plc, the holder of a distribution licence.

ENMAC The system that UK Power Networks is using at Control Centre level to manage its

distribution network.

FPP Trial Zone An area of the EPN distribution network that serves approximately 30km diameter

(700km2) between Peterborough and Cambridge in the East of England, UK.

IEC 61850 The International Electrotechnical Committee’s Standard for the design of electrical

substation automation.

Term Description

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Local Area Network (LAN) Group of computers and associated devices that share a common communications line.

Low Carbon Network Fund (LCNF) A funding mechanism introduced by Ofgem to promote projects that will help all

DNOs understand how they can provide security of supply at value for money as

Britain moves to a low carbon economy.

Modern Protection Relays or A protection scheme to be trialled by the FPP project to overcome the limitations

Novel Protection scheme associated with the use Directional Overcurrent schemes for protection of Grid

transformers.

Ofgem The Office of Gas and Electricity Markets: regulator for the electricity and gas markets

in Great Britain.

On load tap changer A connection point selection mechanism along a power transformer winding that

allows a variable number of turns to be selected in discrete steps.

Point of connection The interface between the UK Power Networks’ equipment (main fuse, energy

meter) and the consumer’s equipment (supply panel).

Quadrature-booster A specialised form of transformer used to control the flow of real power on a three-

phase electricity transmission network.

SCADA Supervisory Control and Data Acquisition: centralised computed-based systems that

monitor and control the electricity distribution network.

Standard Running Arrangements The distribution network configuration under normal network operating conditions.

PI – Data Historian The IT system UK Power Networks is using for collection and archiving of real-time

data and events, mainly measurements from the distribution network.

SNTP (Simple Network Time Protocol) A networking protocol for clock synchronization between computer systems.

Term Description

Flexible Plug and Play A demonstration of the technical characteristics of the Flexible Plug and Play solution

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Contents Definitions 2

1 Executive Summary 6

2 Introduction 8

2.1 Flexible Plug and Play 9

2.2 Flexible Plug and Play: The Trial Zone 10

2.3 Scope of report 11

3 Assumptions and Design Approach 12

3.1 DG Connections and constraints location 13

3.2 FPP technical solution 15

3.3 Learning from the integration process 23

and results

4 Data Communications 24

4.1 Concept 25

4.2 Design 26

4.3 Data optimisation 31

5 Smart Devices 34

5.1 Quadrature-booster and Quadrature-booster 36

Controller System (QBCS)

5.2 Dynamic line rating 38

5.3 Automatic Voltage Controller (AVC) 40

5.4 Remote Terminal Unit 42

5.5 Novel protection relays 45

5.6 Ring Main Units for network reconfiguration 47

6 Smart Applications 48

6.1 Design 50

6.2 Testing and commissioning 55

7 Next steps 57

8 Appendices 59

FiguresFigure 1: Physical architecture 16

Figure 2: Communications architecture 17

Figure 3: FPP integration platform 21

Figure 4: Data engineering process 28

for RTU configuration

Figure 5: Data traffic and DG connections 32

Figure 6: Dynamic line rating 39

architecture diagram

Figure 7: Simplified SuperTAPP n+ Connection 40

Figure 8: General ANM architecture 51

Figure 9: Communication with external 52

applications

Figure 10: ANM production platform for 54

site acceptance test

TablesTable 1: FPP baseline solution 19

Table 2: IEC 61850 integration tools 22

Table 3: IEC 61850 conformance blocks for FPP 29

Table 4: FPP data usage estimation 31

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1Executive Summary


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Executive SummaryThe focus of this report is the design and deployment of the

smart devices and their integration with the ANM system to

a fully operational FPP solution that delivers the specified

functionality. This is an important milestone for the FPP project

as it marks the completion of its construction phase and start

of the trials phase. During trials, the ability of the technical

solution to release headroom in the network and facilitate the

faster and cheaper connection of DG will be tested.

Two DG customers have accepted the FPP connection

offers and their wind farms are planned for connection to

the distribution network in July 2014. Working with real

customers will generate significant learning for the project

but the project has also been designed so that the technical

solution can be tested through simulation in order to de-risk

any potential issues with customer recruitment.

The various components of the technical solution were

supplied by different project partners:

• Smarter Grid Solutions designed, installed and

commissioned the ANM system that will be used to control

generator output;

• Fundamentals Ltd delivered the Quadrature-booster

Controller and the Automatic Voltage Controller relays;

• Alstom Grid provided the novel protection scheme to

overcome the limitations associated with the use of

Directional Overcurrent (DOC) protection and the DLR

solution for 33kV overhead lines; and

• GE Power Conversion has developed the upgraded Remote

Terminal Unit for the substations located into the trial area.

One of the main objectives of the project was to develop

the FPP technical solution on an open standard architecture

using the IEC 61850 substations communication standard for

the integration of the ANM system and the smart devices.

The specific standard was chosen in order to gain experience

Flexible Plug and Play (FPP) is a Second Tier Low Carbon

Network Fund (LCNF) project that aims to connect distributed

generation (DG) onto constrained parts of the electricity

distribution network without the need for conventional

network reinforcement. To achieve this, innovative technical

and commercial solutions are being trialled to manage

constraints and maximise network utilisation.

TheFPPtechnicalsolutionisbasedonthreemain

components:

1. A communications infrastructure to facilitate integrated

operation of the geographically disparate components

that make up the FPP technical solution. The design and

commissioning of the communication infrastructure has

been a key milestone for the project and was completed in

March 20131.

2. Power systems devices in the field (also referred

to as “smart devices”) which are connected to the

communication infrastructure and which provide control

and monitoring capabilities. One of these devices is the

Quadrature-booster which was commissioned in July 20132.

Other devices are the Dynamic Line Rating (DLR) system

for 33kV overhead lines, the novel protection relays, the

upgraded Remote Terminal Units (RTU), the Generator

Controllers and the Automatic Voltage Control (AVC) Relays.

These devices are deployed as point solutions that resolve

local constraints and release additional headroom in the

existing infrastructure for connection of DG.

3. A centralised Active Network Management (ANM) system

which provides overarching management of the various

functional and controllable elements that make up the FPP

technical solution; The ANM system enables the overall

integration of the various point solutions into a coordinated

system approach.

1 SDRC 9.3 - Communications Platform report, available at www.flexibleplugandplay.co.uk 2 SDRC 9.8 – Deployment of Quadrature-Booster within the trial area report, available at www.flexibleplugandplay.co.uk


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with its use and explore whether its engineering structure

and definition could ease integration and reduce engineering

time for applications in smart grid projects.

The project achieved its main milestone of commissioning

the FPP solution while pushing the boundaries of technical

and organisational innovation in a number of areas including:

TheDNOasthesystemintegrator

The FPP project involves significant information and

communication technology elements to solve power systems

problems. The relevant work activities associated with the

delivery of the technical solutions were structured in four

distinct work packages:

• Workstream 1 Delivery of the Communications

Infrastructure

• Workstream 2 Delivery of the Smart Devices

• Workstream 4 Delivery of the Active Network

Management system

• Workstream 8 Systems Integration

The Systems Integration workstream working closely with the

Technical Design Authority function ensured an integrated

approach and process in designing and testing the systems

installed. The testing approach involved different stages

of testing including a pre-production integration platform

which was used to test all components and prove their

interoperability before commissioning in the live operational

distribution network.

UK Power Networks’ subject matter experts from a number

of departments including Information Systems, Operational

Telecommunications, Asset Management and the FPP project

teams worked together with external input where required

to design, install and test the systems.

The project at its inception decided to keep in-house the

majority of the Systems Integration work in order to develop

skills and retain a significant proportion of the knowledge

generated.

ImplementationofIEC61850substationcommunications

protocol

The project has delivered the open standards architecture by

implementing a data communication infrastructure using the

IEC 61850 standard. The IEC 61850 standard is widely used

inside the boundary of the individual electrical substation

boundaries for protection scheme applications; however

the project is using it in a novel way both in terms of

communication between multiple substations and also over

a wireless mesh network.

The novel approach in the use of the standard meant that

key challenges such as data and traffic optimisation had

to be tackled generating significant learning and providing

an initial understanding on the potential for scalability and

application of such technologies.

This report outlines the design, testing, installation and

commissioning of the FPP technical solution and it marks

the successful completion of the Successful Delivery Reward

Criterion (SDRC) for the Demonstration of FPP technical

characteristics of FPP solution referenced as 9.4 in the Project

Direction.

The FPP project intends to disseminate further information on

the learning outcomes and performance of the FPP technical

solution during the trial phase of the project.

Introduction

2


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Flexible Plug and Play (FPP)2.1The FPP project, funded under Ofgem’s LCNF Second Tier

mechanism, aims to facilitate the faster and cheaper

connection of DG onto the distribution electricity network

without the need for conventional network reinforcement.

The FPP methods achieve this objective by managing network

constraints and maximising network utilisation, which will be

conducted through the integration of smart devices, smart

applications and smart commercial arrangements.

The project, led by UK Power Networks, addresses this

requirement in partnership with ten project partners:

Vodafone (formally Cable & Wireless Worldwide), Silver

Spring Networks, Alstom Grid, Smarter Grid Solutions, GL

Garrad Hassan, University of Cambridge, Imperial College

London, the Institution of Engineering and Technology,

Fundamentals Ltd and GE Power Conversion.


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Flexible Plug and Play: The trial zone2.2The location chosen for the FPP project is an area of

UK Power Networks’ EPN distribution network that

serves approximately 30km diameter (700km²) between

Peterborough and Cambridge (the FPP Trial Zone) in the East

of England, UK. This area is favourable to DG developers,

wind and solar farms in particular, due to geography and

favourable weather conditions3.

Over recent years UK Power Networks has experienced

increased activity in DG development in this area, and a

rapid rise in connection applications; existing renewable

DG connections total 144MW, with 158MW of DG capacity

currently at various stages of the planning process seeking

to connect as at July 2013. Using conventional connection

approaches, the connection of this anticipated growth in

DG is expected to require significant network reinforcement

to manage network thermal and voltage constraints and

reverse power flow issues.

For this reason, the area between Peterborough and

Cambridge serves as an ideal trial area for the FPP project to

explore alternative smart connection solutions.

An extensive set of trials aligned with the project’s use cases

will run from Q3 2013 to Q4 2014 in order to generate key

learning outcomes that the project is seeking to deliver both

in terms of facilitating cheaper and faster connections and

the performance of the overall technical solution that has

been installed.

3 http://www.ukpowernetworks.co.uk/internet/en/connections/documents/HQ-2000-4702-D.pdf


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Scope of report2.3This report summarises the work associated with the design

and deployment of the FPP technical solution and the

completion of SDRC 9.4 (A Demonstration of the Flexible

Plug and Play technical characteristics of the FPP technical

solution) by end of September 2013 as described in the FPP

Project Direction. The successful completion of the SDRC is

evidenced by the commissioning of the different components

of the architecture and this report, a catalogue of available

evidence can be found in Appendix 5.

In addition, this report provides an initial insight to the learning

available to other Great Britain distribution network operators

when designing, installing and commissioning similar systems

and gives an indication of the learning that will be generated

by the project during the trials phase (Q4 2013 to Q4 2014).

Thereportisstructuredasfollows:

Section3 Outlines the design approach that has driven

the specifications of the technical solution and

describes the strategy to ensure the integration

of the overall FPP solution.

Section4 Provides the key elements considered for the data

communication design and implementation.

Section5 Details the overall process going from the

requirements and specifications up to the final

commissioning on site for all the smart devices.

Section6 Focuses on the smart applications. The section

highlights the specifications retained for the

implementation of the ANM system and the

process driven to the acceptance of the solution.

Section7 Concludes the report and highlights the main

learning.

Appendix5summarisesthekeydocumentsavailablethat

evidencetheSDRCrequirementsaslistedbelow:

• Installation and commissioning documentation of IEDs and

other field devices necessary to support the trials and in

accordance with the specification included in the contracts

with the relevant partners.

• Installation and commissioning documentation of production

of smart applications in accordance with the specification

included in the contracts with the relevant partners.

• Pre-production interoperability test results for FPP’s smart

devices and smart applications.

• IEC 61850 certification for all relevant Remote Terminal Units

(RTU), Intelligent Electrical Devices (IED) and other IEC 61850

field devices.

A list of the key project documents generated during

completion of this work that are available to GB DNOs is

included in Appendix 6.

3Assumptions and Design Approach


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DG connections and constraints location3.1As of July 2013, the potential for renewable generation in

the trial area is approximately at 302MW of capacity and

consists of 144MW of connected DG and a further 158MW of

DG capacity at various stages within the connections process.

The size of the projects varies from 0.25MW up to the largest

at 18.5MW, all of which are proposed for connection in the

11kV, 33kV and 132kV distribution network.

Theconnectionofthesegeneratorswillcausespecific

issuesthathavebeenidentifiedincluding:

• Thermalconstraints: Thermal overloads arising at certain

pinch points, partly due to the natural flow of power

through the interconnected network, which leaves some

capacity under utilised.

• Increaseinreversepowerflows: Existing Grid substation

transformers have limits on reverse power flow, which

is due to the allowable Directional Overcurrent (DOC)

protection settings and the size of the Grid transformers.

• Voltageconstraints: Voltage control is made more difficult

by the changes in power flows, particularly reverse power

flow through tap changer transformers. The connection

of DG on the 11kV side at primary substations may cause

voltage levels to be outside of statutory limits.

Appendix 1 presents a simplified single line diagram for

the FPP trial area including all the DG connections and the

constraint locations described below. The generators are

categorised as those that currently connected, those that have

accepted their connection offers and those that are at different

stages of planning and might materialise in the future.

3.1.1ConnectionsfeedingintoMarchGrid(reverse

powerflows)

Any connections within this area of the network, at any voltage

(EHV, HV or LV), would increase reverse power flow from 33kV to

the upstream 132kV network. The existing infrastructure within

the FPP project area consists of a small number of 132kV grid

supply points and an interconnected 33kV network supplying

small 33/11kV primary substations. The main limitation

on March Grid is the reverse power capacity, considerably

before the grid transformer reaches its thermal or tap change

capabilities, which is limited by the maximum settings that

can be applied to the Directional Overcurrent (DOC) protection.

The present limitations are 2 x 45MVA transformers, maximum

DOC setting 75% x 45MA = 34MVA under N-1 condition when

one of the grid transformer circuit is out of service. Although

some additional spare capacity could be released through

the replacement of the existing protection system, this would

only provide a further approximately 11MW of headroom

which, when compared to an aggregated total of 19.75MW of

requested exports and the potential for increases in the uptake

of small scale generation, it would quickly be exceeded.

The first of the FPP accepted offers (a wind farm of 10MW

capacity) will connect in the area of March Grid utilising the ANM

technology in order to manage the reverse power flow constraint.

The connection is planned for energisation in summer 2014.

3.1.2ConnectionsintoPeterboroughCentralGrid(reverse

powerflows)

Any connections within this area of the network, at any

voltage (EHV, HV or LV), would reduce load at Peterborough

Grid 33kV, and therefore increase reverse power flow from

33kV to the upstream 132kV network. The main limitation on

Peterborough Central Grid is the reverse power capacity, well

before the grid transformer reaches its thermal or tap change


can be applied to the Directional Overcurrent protection. The

present limitations are 2 x 60MVA grid transformers, maximum

DOC setting 75% x 60MA = 42MVA under N-1 condition when

one of the grid transformer circuit is out of service. The projected

worst- case reverse power flow with the existing generation

is approximately 13MW. Whilst the spare capacity is currently

32MW, there is a further 30.9MW of aggregated generation


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accepting additional DG onto the distribution network.

3.1.6ConnectionsontoMarchPrimary(voltagerise)

The high penetration of DG around the March Grid significantly

changes behaviour of the distribution network around that area.

High volumes of generation connecting on the network affects

the voltage profile on the distribution network, and possible

unacceptable voltage rise at the point of common coupling (PCC).

Like other distribution networks, the original design does not

consider bi-directional power flows, voltage rise contributions

from DG, and other associated impacts. As a result standard

voltage regulation strategies are unable to satisfactorily deal

with these problems. Therefore, novel solutions are required.

3.1.7ConnectionsontoChatterisPrimary(voltagerise)

Voltage level studies show possible fluctuations when

distributed generators are connected. When planned

generators are connected the indicative voltage rise at

Chatteris 11kV is 1.043pu, which is close to the 6% limit, and

leaves little headroom for the connection of further DG.

3.1.8ConnectionsontoNorthwoldandDownhamMarket

33kVlines(thermal–powerflowbalance)

The 33kV Northwold overhead line and the 33kV Downham

Market overhead line operate in parallel with differing source

impedances resulting in unbalanced load sharing. The full capacity

of all the lines cannot be used because Northwold reaches its

full capacity limit when the other line is at two thirds of its fully

capacity. This is a common constraint where the 33kV network runs

interconnected. This constraint restricts the seasonal export of the

local CHP plant at Wissington British Sugar factory, and constrains

connection of additional generation along the Downham Market

line. To increase utilisation of the 33kV line capacities out of

Wissington, the parallel circuits required to be augmented with

series-connected impedance addition/reduction capabilities.

The added (or compensated) impedance is chosen such that the

power flow balance between the parallel lines is improved.

expected to be connected in the area, along with the potential

for increases in the uptake of small scale generation.

3.1.3ConnectionsontoBury–PeterboroughCentral33kV

circuit(thermal)

This zone involves a 20.7km overhead line through areas around

Bury, Farcet and Ramsey. Any connections within the area on

the 33kV network, especially between Bury Primary and Farcet

Primary where the conductor is smallest, would increase thermal

loading on this circuit beyond its limits (23MW summer rating).

One of the two accepted FPP connections (wind farm, 7.2MW

capacity) will utilise this line and the constraint will be

managed through a combination of application of dynamic

line rating and ANM technology. The connection is currently

planned for energisation in Q2 2014.

3.1.4ConnectionsbetweenMarch/ChatterisT2Teepoint–

FunthamsLaneT233kVOHLcircuit(thermal)

There is a dense distribution of wind farms connected to this

overhead line (OHL), which currently forms a bottleneck for

the connection of further DG in the area as the current capacity

is near the thermal rating of the overhead line conductor.

3.1.5ConnectionsbetweenMarchGrid–WhittleseyT2/

ChatterisT233kVcircuit(thermal)

This section of network comprises of 5.06km overhead line

conductor all rated 23MW (summer). This rating is based on

static seasonal ratings traditionally applied to overhead lines –

summer, autumn/spring and winter which are based on ENA

Engineering Recommendation (ER) P27. A total of 10.75MW of

firm generation export has already been connected on this line,

with a further 17.5MW of generation requesting connection.

This would increase the loading to 28.25MW, which exceeds the

23MW summer capacity rating of the line. This and any further

connections would therefore impact on the thermal loading

of this 33kV circuit and its capacity would form a constraint in


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FPP technical solution3.23.2.1OverviewoftheFPPtechnicalsolution

In context of the above constraint scenarios a technical solution

is required to enable a seamless integration of new distributed

generators within the trial area with an autonomous and real

time management of those network constraints. The technical

solution, comprising of a range of solutions, is designed to cater

for single or combination of constraints at a single location and

is able to evolve and adapt to changes in network conditions

caused by addition of new generators.

The technical solution involves the implementation of a smart

grid architecture using smart devices and ANM over an Internet-

Protocol (IP)-enabled communications backbone, in parallel

with UK Power Networks’ existing Supervisory Control and Data

Acquisition (SCADA) and related communications infrastructure.

The FPP project is seeking to prove that the technical solutions

can work together to deliver their specified functionality and

should distributed generators are willing to connect during the

life time of the project then their faster and cheaper connection

can be facilitated.

In essence the function of the FPP technical solution is to actively

manage real and reactive power flows on the distribution

network in response to prevailing network conditions to

maximise generation output/export whilst ensuring that

dynamically calculated network constraints are not breached.

This may be achieved through a combination of distributed

autonomous control actions and centralised co-ordinated

control actions, including control of generator output.


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Physical architecture

Figure 1 illustrates the physical architecture of the FPP technical

solution, highlighting the key physical elements of the solution.

The equipment installed at control level (ENMAC, Active

Network Management, ODS (Operational Data Store)/PI – see

definitions) comprises mainly of servers located in data centres.

The equipment that is located in substations or in the field, such

as RTUs, smart devices and local ANM controllers comprises

mainly of industrial computers. It also illustrates where existing

communications (legacy system) and new radio frequency

mesh wide area communication infrastructure will be used.

3.2.2 Architecture of the FPP technical solution

SCADA systems in the majority of power industries typically

operate in a centralised management model providing both

monitoring and control facilities. The FPP architecture has

adopted a similar model with a centralised ANM system

which interfaces with the existing UK Power Networks’ SCADA

system but operates independently at both functional and

non-functional levels. By the virtue of this model, every design

aspect ensures that no element of the FPP architecture will

interfere with the existing IT and SCADA infrastructure during

the FPP trial phase. The separation of the two infrastructures

was a key business requirement for the trial to ensure that the

new FPP systems have no impact on the business-as-usual

operation of the existing systems.

Figure 1: Physical architecture

ENMAC Active Network Management system ODS/PI

Generator/circuit breaker

Weather stationand CTs

Tap changerQuad booster

Novel Protection SchemeRTU in Local Control Unit

Ring Main Units

Existingmeasurements/Status of network

Quad Booster Control System Local ANM ControllerDynamic Line Rating Relay

Weather stationLeg

acy Co

mms

RF CommsRF Co

mms

RF C

omm

s

RF Comm

s

RF Comms

RF CommsRF Comm

s

Automatic Voltage Controller

Flexible Plug and Play Successful Reward Delivery Criteria 9.4 Report

UK Power Networks (Operations) Limited. Registered in England and Wales. Registered No. 3870728. Registered Office: Newington House, 237 Southwark Bridge Road, London, SE1 6NP Page18 of 55

The equipment used to form the integration platform (please refer to Figure 3 for the relevant schematic):

• ANM Pre-‐production platform • 3 RF mesh devices (2 remote E-‐bridges and 1 master E-‐bridge)

• 1 measurement simulator (OMICRON) • 1 computer to run IEC 61850 Integration tools (see next section) • 1 optical switch

Figure 3: FPP integration platform

Client/Server Simulator

Generator Controller Generator Controller

RF comms

Ethernet Switch

MastereBridge

Remote eBridge

Smart ApplicationsFront End

Generator Simulator

Optical/Ethernetswitch

RTU

Ethernet

Measurements Simulator

Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet

ANM Pre-ProductionPlatfrom










RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet



RTU (Upgraded)

FPP high level architecture VO 3.vsd

FPP physical architecture 23/09/2013


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Communications architecture

The second architectural diagram in Figure 2 provides view of

the entire communications architecture. This diagram presents

the architecture in three communications levels: operations

level (control centre), station level (substation) and bay level

(device) in order to categorise the functionality and location

of the components. The diagram also distinguishes between

existing and business as usual components as and new FPP

components using white background and yellow background

symbols respectively. This diagram also illustrates at a high level

the network connections between the various components

such as the connection of ANM system to UK Power Networks

applications at the operations level and interconnection of

substation devices at the station level.

Figure 2: Communications architecture

Substation LAN

UKPN RTU

RF ebridge

Ope

ratio

ns le

vel

Stat

ion

leve

lBa

y le

vel

ENMAC SCADA

VodafoneMSP WAN

Hardwired

Hardwired

Hardwired Hardwired

TEC (Telecontrol equipment cubicle)

UKPN RTU

ANM Local Controller TEC

MSP = Multi Services PlatformWAN = Wide Area Network

Digital data link

Substation LAN

HMIHMI

UKPN control centre

UKPN SCADA

FPP Silver SpringsRF Mesh

UKPN SCADA

RF ebridge

Plant measurements

Novel Protection

Relay

Quad BoosterControl System

Automatic Voltage Controller

Dynamic LineRating Relay

Generator control System

Customercircuit

breaker

UKPNcircuit

breaker

UKPNRTU

RFebridge

GeneratorController

PI Historian

ANM

Key

Fibre

CAT5e

Copper link/Hard wire

New FPP equipment

Existing equipment


18 |

3.2.3SmartDevicesandSmartApplications

TheFPPtechnicalsolutionconsistsofthefollowingkey

components:

SmartApplications:

• In order to keep the network within limits by controlling

interruptible distributed generators, two smart applications will

be trialled; one to manage to the power flows and the second

one to manage the voltage.

• A third smart application will also be trialled in order to provide

dynamic thermal rating of overhead lines at the central

application level.

SmartDevices:

• AQuadrature-boosterandQuadrature-boosterController

System (QBCS)4: The QBCS automatically controls the tap

position of the Quadrature-booster in order to manage power

flows in a parallel circuit. The ANM system is required to monitor

and control the generator output in order to optimise the flow

of power in the circuits, without conflict with the QBCS. The QBCS

will provide information to the ANM system, which will also use

measurements at Wissington substation to define optimal level

of generation output.

• DynamicLineRating(DLR): The function of the dynamic line

rating will be to monitor local weather station data and calculate

ampacity5 ratings based on the real weather conditions. The

ampacity ratings will be provided to the ANM system, which

will dynamically manage thermal constraints. According to the

generators and constraint locations.

• AutomaticVoltageController(AVC): The primary function

of the AVC will be to monitor the voltage level (11kV or 33kV)

by controlling the transformer On Load Tap Changer (OLTC) to

maintain voltages on the electrical network which it supplies

within appropriate/statutory limits. In the perspective of the

trial, two AVC schemes will be installed. They will monitor and

manage the voltage constraints that may occur mainly if new

generators will be connected on the 11kV grid. The devices will

also provide information the ANM system. The AVC devices are

delivered by Fundamentals.

• NovelProtectionRelays: The function of the novel protection

relay will be to trial alternative schemes to directional overcurrent

protection at specific locations within the FPP trial area, in order

to accommodate potential reverse power flows. The trials will

involve initial deployment of novel protection relays in an alarm

only configuration, in parallel with existing protection schemes.

The novel protection relay is delivered by Alstom Grid UK Ltd.

• UpgradedRTUs: The boundaries of the trial area are defined

by the electrical network feed by two Grid substations and

ten primary substations. These substations will be upgraded

to provide relevant measurements to the smart applications

using a standard protocol (IEC 61850). The upgraded RTUs are

delivered by GE Power Conversion.

Table 1 provides a summary of the equipment that has been

commissioned and makes up the FPP technical solution.

4 SDRC 9.8 – Deployment of Quadrature-Booster within the trial area report, available at www.flexibleplugandplay.co.uk 5 Ampacity is defined as the maximum amount of electrical current a conductor or device can carry


| 19

Table 1: FPP baseline solution

Power Flow Smart Application ANM UK Power Networks’ Control Centre

Voltage Smart Application ANM UK Power Networks’ Control Centre

Dynamic Rating Smart Application ANM UK Power Networks’ Control Centre

Generator Controllers (four) Generator substations

Quadrature-Booster Control System TapCON 260 relay (MR) Wissington substation

DLR1A and DLR1B Micom P341 relay (Alstom) Farcet Primary substation

M871 data logger

Lufft WS501-UMB compact weather station

DISCOS optical current sensors

DLR2 Micom P341 relay (Alstom) Funthams Lane Primary substation

M871 data logger


DISCOS optical current sensors

DLR4 Micom P341 relay (Alstom) March Grid substation

M871 data logger


AVC1 SuperTAPP n+ (Fundamentals) March Grid substation

AVC2 SuperTAPP n+ (Fundamentals) March Primary substation

MPR1 (Novel Protection Relays) Micom P142 relays (Alstom) March Grid

MPR2 (Novel Protection Relays) Micom P142 relays (Alstom) Peterborough Central

Upgraded substation RTUs (12) T5500 (GE) March Grid GS

Wissington

Farcet Primary

Peterborough Central GS

Chatteris Primary

Funthams Lane Primary

March Primary

Bury Primary

Littleport Primary

Northwold Primary

Whittlesey Primary

Southery Primary

FlexiblePlugandPlay Equipment CommissioningSitetechnicalsolution


20 |

TestingandintegrationapproachoftheFPPtechnical

solution

One of the main challenges of the project was the testing

and integration of various components into a functional and

scalable solution that delivers the project’s objectives. It was

recognised during the bid stage that the integration process

was a key risk for the project that could impact both the

quality of the technical solution and the delivery timescales.

In order to mitigate this, a comprehensive testing approach

was developed including different stages of testing and the

set-up of an integration laboratory in UK Power Networks’

premises where the interoperability testing could be carried

out prior to deployment into the live operational environment.

The responsibility for the testing and integration process

was shared between the FPP Workstream Managers,

FPP Project Manager and Design Authority. In addition,

UK Power Networks’ subject matter experts in specific areas

such as Real-Time Systems, Information Systems and Capital

Programme were engaged alongside specialised personnel

from the various project partners and suppliers in order to

carry out the various tests.

3.2.4Testinglevels

TheFPPprocessoftestingwasbasedonfollowing

approach:

1.Unittests: Unit testing is the first to take place; it does not

test the overall system but only partial parts that have been

developed separately. Each unit test case is independent

from the others. These unit tests may involve substitutes

like mock-up devices and test harnesses to assist testing

a product in isolation. Also some local integration tests

(related to software or devices) can be also done to prepare

the systems for integration testing. These tests include

technical and functional aspects.

2.Integrationandinteroperabilitytests: System integration

testing is the process that exercises a FPP product’s

coexistence with others. The system integration process

tested the FPP products required interactions with the whole

FPP solution. The FPP architecture uses a standard protocol for

data exchange; as such interoperability tests are part of the

integration tests.

All the integration tests are described into the System

Integration Test Specification document6. The system

integration testing involves:

• Data integration tests: These tests are designed to

demonstrate the interoperability of different components

implementing the same protocol. For that purpose, these

tests validate the communication between the IEC 61850

Client, the ANM servers, the IEC 61850 servers and smart

devices, under test over the proposed communication

channels for FPP. Data integration testing will not exercise

the full range of data exchange made possible by IEC 61850,

only the data exchange required by FPP will be tested.

• End-to-endfunctional: These tests exercised a subset of

the functionality set out in the FPP Functional Use Cases. The

integration testing can expose problems with the interfaces

among the system components before trouble occurs in real-

world system operation. At the interface the tests aimed to

validate the communication (RF Mesh) and the protocol (IEC

61850). The integration testing is completed progressively

until the entire system has been integrated. Once all the

integration testing in the laboratory is completed the site

acceptance tests are carried out to ensure the operation of

the system in a live environment.

Note: As part of the High Level Test Approach7 the test design also

describes the non-functional tests based on the non-functional

requirements as defined in the Functional and Non-functional

Requirement Specifications document8. Non-functional testing

6 DA P0250.FPP Scope of Work WS8 testing and system integration v1.07 DA.P0202.FPP High level Test Approach v1.08 DA.P0154.FPP Functional and Non-Functional Requirements Specification v1.0


| 21

can be done at different level of the testing strategy (during

unit, integration or acceptance tests) depending on the non-

functional requirement to test.

3.2.5 Testing environment

In order to deliver the testing planned, the different project

partners have setup their own test environments for unit testing

and for the factory acceptance test of the components they

were responsible for providing. As several components needed

to be implemented and integrated to provide the overall

FPP solution, the FPP project has setup its own independent

integration platform:

3.2.5.1 Integration platform

The integration platform is based on the ANM Pre-production

platform developed and commissioned as part of the ANM

system project delivery. This is a reduced platform of the overall

FPP technical solution allowing system integration and end-to-

end testing with real equipment or integration tools. It ensures

that the system is running with the right level of functionality

and the minimum risk of failure before going on the trial. The

hardware has been rolled-out into a UK Power Networks premise

to form an integration laboratory. Communications equipment

(radio frequency mesh devices) has been used to create a local

Radio Frequency (RF) mesh communication network.

The equipment used to form the integration platform

(please refer to Figure 3 for the relevant schematic):

• ANM Pre-production platform

• 3 RF mesh devices (2 remote E-bridges and 1 master E-bridge)

• 1 measurement simulator (OMICRON)

• 1 computer to run IEC 61850 Integration tools (see next

section)

• 1 optical switch










RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet



Client/Server Simulator Front End Smart Applications

MastereBridge


Generator Simulator

Remote eBridgeEthernet

ANM Pre-Production Platform

ANM Pre-Production Platform

RF Co

mmsRF Comms

Ethernet

Ethernet

Remote eBridge

Fibre

Fibre

Wired

Fibre

Wired

Wired Wired

AVCRTU DLRQBCS









RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet











RF comms

Ethernet Switch

MastereBridge

Remote eBridge


Generator Simulator


RTU

Ethernet


Wired

Ethernet Ethenet

Remote eBridge

RF comms

Ethernet

QBCS DLR AVC

Wired

Wired

Wired

Fibre Fibre

Fibre

Ethernet




EthernetEthernet

Generator ControllerGenerator Controller

Ethernet Switch


22 |

3.2.5.2 Integration tools

As part of the technical support on IEC 61850 implementation,

DNV KEMA was instructed to carry out an independent

evaluation and recommendation of data engineering, testing

and simulation tools. UK Power Networks’ internal stakeholders

were engaged in brainstorming workshop to identify core UK

Power Networks and FPP project requirements for the tools. A

requirement specification was subsequently created for each

tool which formed part of an information request to vendors

and essentially dictated the selection process. The following

tools were selected and procured for the FPP project.

These tools are used during the implementation of IEC 61850

in the project. Tool training was also organised for FPP team

members as well as relevant UK Power Networks’ staff likely

to be involved in future maintenance or implementation.

Further work will be carried out by FPP project team during

the trial phase to enable smooth business as usual handover

of these tools.

Table 2: IEC 61850 integration tools

1 Server Simulator Triangle Microworks ANVIL Simulates smart devices acting as IEC 61850 servers

2 Client Simulator Triangle Microworks HAMMER Simulates ANM acting as IEC 61850 client

3 Data Analyser KEMA UniCA Analyser Protocol analyser for error detection and

communications testing

4 Substation Configuration UniCA SCL Checker The SCL checker is used for validation of (SCL) files

Language (SCL) Checker

5 IED Capability Description Helinks STS The ICD Editor creates the ICD file used to configure

(ICD) Editor a server or a smart device

6 System Configurator Helinks STS The system configurator combines the ICD files into

one Substation Configuration Description (SCD)

file. This SCD file is imported in the Manufacturer

specific IED configurators.

No. IEC61850Tool SelectedProduct Function


| 23

Learning from the integrationprocess and results

3.3

The integration tests of the different components of the

FPP technical solution have required the team to manage

a large number of dependencies within the Project. Project

partners and project suppliers were involved in the delivery

of the smart applications and the Smart Devices. Using the

project plan, the FPP System Integration workstream setup

up the integration plan and identified the dependencies

with other workstreams. When the integration platform was

commissioned the integration process started with the aim

to integrate one by one the various elements of the FPP

technical solution. This process took six months to carry out

and three months before that to plan.

The challenge faced during this stage was the availability of

new skills to implement the IEC 61850 standard. To develop

new competencies, the project contracted technical support

and training. Specifically, DNV KEMA was engaged to provide

support with the design and implementation of the IEC 61850

project across the project. DNV KEMA worked very closely

with the rest of the FPP project participants and UK Power

Networks’ experts from the Information Systems, Operational

Telecommunications and Real-Time Systems teams.

It became evident that the integration of new generation

of relays and RTUs has changed with the introduction of

information and communication technologies within the

substation; operations that were traditionally the domain of

power systems engineers now could require additional skills

such understanding of IP networking, data communications

and data modelling.

In term of results, all the components of the FPP technical

solution have been successfully integrated following the

tests described into the System Integration Test Specification9

document. The results of these tests have been captured

by completing the test document and providing various

records (traces, logs and videos) in order to evidence the

pre-production interoperability test results for FPP’s smart

devices.

After the completion of the integration stage, the smart

devices and the smart application have been installed and

commissioned on site as detailed in the next sections.

9 WS08.P0142.FPP Integration Tests specification

4Data Communications


| 25

Concept4.1Data communication is an integral part of the FPP solution as

the FPP project concept relies on a system capable of real time

interaction between its components across wide geographic

area following innovative model of active management as

opposed to the traditional passive management. Essentially,

the core role of data communication in FPP is to enable

ANM to receive data relating to generator power export

and network constraint status so that any generator control

instructions from ANM can then be swiftly transmitted to

generator control system.

There are mainly three elements involved, communications

infrastructure, communications protocol and communications

equipment; the former two are detailed below and the latter

has been covered within various sections of this report.


26 |

Design4.24.2.1Communicationsinfrastructure

The FPP communications infrastructure is based on a multi-

layered architecture consisting of ANM Local Area Network

(LAN) at the operations level and substation LAN at the station

level, connected together by the FPP communications solution

comprising of RF Mesh Network and Wide Area Network

(WAN). The entire FPP infrastructure is capable of supporting

IP-based communications including IP-based protocols defined

by Distributed Network Protocol 3.0 (DNP3) and IEC 61850

standard. The communications infrastructure has been designed

to provide the highest degree of resilience and availability in line

with the standards of existing SCADA infrastructure particularly,

with consideration of design principles mentioned above.

RFMeshNetwork

In comparison to the widely implemented star or ring

topology in power industry, FPP project is implementing radio

communications mesh network topology which offers additional

benefits coupled with fresh challenges. The RF Mesh technology

acts as the primary connectivity between substations and the

end FPP generator sites, commonly known as the “last mile”

connection. The mesh network interfaces to FPP WAN via two

back-haul links presented at two grid substations providing dual

redundancy. The IP-based RF Mesh operates on sub-GHz radio

spectrum, 870-876 MHz, delivering the required propagation

and performance while supporting a practical data rate for

current and future smart grid services.

The mesh network is designed to provide radio canopy over

the FPP trial area thereby, making it easy to connect any future

generator customer. The mesh topology ensures that every

remote node always has multiple routes to a master node. One

of the fundamental differences to traditional network is that the

devices are able to communicate with each other in a peer-to-

peer fashion, without all communication passing through the

central firewalls adding another dimension to FPP security design

work. Further details on the RF mesh design and deployment

are given in FPP SDRC report 9.3 which is available on the FPP

website (www.flexibleplugandplay.co.uk).

WideAreaNetwork

RF mesh network utilises Vodafone Multi Service Platform (MSP)

to connect to the ANM LAN via two back-haul links. The MSP is

an IP-based network that provides a proven, secure and high

availability platform already in use as UK Power Networks’ core

communications IP backbone network. The WAN also enables

connectivity to Silver Spring Networks and Smarter Grid Solutions

via secure VPN (Virtual Private Network) tunnel connections.

Data traffic is logically segregated within the WAN using secure

sub-networks known as VRF (Virtual Routing and Forwarding).

Further details on the WAN design and deployment are given in

FPP SDRC report 9.3.

ANMLocalAreaNetwork

The ANM system is installed within UK Power Networks

Control Centre LAN in the form of a controlled sub-network

commonly known as DMZ (Demilitarised zone). With a firewall

separating the FPP network from the rest of UK Power Networks

infrastructure, DMZ provides additional layer of security. Over the

secured connection ANM exchanges data with SCADA servers,

PI Data Historian servers and the UK Power Networks Simple

Network Time Protocol (SNTP) time server.

SubstationLocalAreaNetwork

Similar to the concept of ANM LAN segregation at the Operations

level, FPP design also adopts similar approach at the station level

with implementation of FPP substation LAN. This serves two

primary functions; firstly to provide a medium for information

exchange between components of the FPP Technical Solution

which are co-located in the same substation; and secondly to

interface with RF mesh linking to the FPP WAN. There was no

standard in UK Power Networks for substation LAN, accordingly

the FPP project undertook extensive design work in this area


| 27

which aimed to provide technical reference for future projects.

Following key areas are covered as part of FPP substation LAN

design and implementation:

• LANTopology: Single switch star topology is implemented

which offers simplicity in design and maintenance.

• LAN switch implementation: Having assessed multiple

products against FPP requirement a Layer 3 Ethernet switch

is selected which supports multiple fibre and copper ports.

Wherever possible fibre cables are used for LAN connections

external to cabinets to mitigate issues from electromagnetic

interference.

• IP Addressing: FPP has implemented 27 bit subnet IP

addresses allowing 30 usable addresses for FPP devices in

each primary substation, a future-proofed approach that

would cater for significant amount of additional devices.

• Security: The substation LAN will be physically and logically

separate to other UK Power Networks’ network. It was

ensured that the LAN switch supports the security features

specified by the FPP security design requirements.

4.2.2Communicationprotocols

IEC61850FPPrequirements

The International Electrical Committee (IEC), representatives

from both utilities and suppliers have jointly elaborated the new

standard IEC 61850 “Communication Networks and Systems in

Substations”. Gaining acceptance worldwide, IEC 61850 is the first

and only global standard that considers all the communication

needs within substations.

The general scope of the standard is designed to support the

communication of all functions being performed in the substation.

Its main goal is interoperability; this is the ability for IEDs from one

or different manufacturers to exchange information and use the

information for their own functions. This point is very relevant

for the FPP context which aims to design an interoperable and

scalable solution able to cope with future requirements.

Although this protocol has been initially designed to implement

internal substation communication, the innovations brought by

the project are:

• To consider this protocol for communication between the

field devices and the centralised ANM server. The ANM

at the Control Centre will be acting as an IEC 61850 client

to communicate with the remote devices acting as IEC

61850 servers. The remote devices include substation RTUs,

Generator Controller and smart devices such as Dynamic Line

Rating relay, Quadrature-booster Control relay and Automatic

Voltage Controller.

• To implement IEC61850 protocol on a low bandwidth (when

compared to high bandwidth communications usually

available within the substation) communication medium such

as RF mesh.

For clarity, the FPP technical solution will use the following

elements of IEC 61850 standard communications as defined in

IEC 61850-8-1 part:

• Core Abstract Communication Server Interface (ACSI) services,

which are supported via Manufacturing Message Specification

(MMS) Protocol Suite support.

• Time synchronisation services, which are supported via SNTP

support.

As consequence, the use of Sampled Values (SV), Generic Object

Oriented Substation Events (GOOSE) and Generic Substation

State Events (GSSE) is out of scope of FPP.

IEC61850dataconfiguration

The data model of the IEC 61850 standard is an object-

oriented one, grouping the data into the smallest possible sets

referring to the smallest possible functions to be implemented

independently. These smallest possible data groups or functions

are named Logical Nodes. The Logical Nodes and all Data and

Attributes contained are named according to a standardised

semantic, which is mandatory.


28 |

A prerequisite for the project is the use of components, which are

proven to be compliant with IEC 61850. Each IED/Smart Devices

supplier provided a conformance test certificate for each device to

be used in the FPP solution.

In the IEC 61850 standard, all the files used to configure

compliant devices are written following a dedicated XML syntax:

the Substation Configuration description Language (SCL). In

order to document its data model each device is delivered with

a SCL file called IED Capability Description file (ICD). When the

devices are ready to be integrated into a system, the Configured

IED Description file (CID) describes all configuration parameters

relevant for that IED (IP address, Report Control Blocks). This file is

used as input to the ANM system (acting as an IEC 61850 Client)

to interact with the devices (acting as IEC 61850 Servers).

All the field devices used in the FPP solution, have been delivered

and tested with the appropriate ICD/CID files in order to be

integrated with the ANM system.

In the particular case of the FPP substation RTUs, which implement

an IEC 61850 Server, the capability is also described by a SCL file

of type .ICD which incorporates all of the relevant Logical Nodes

from the IEC 61850 data model in order to model the substation.

This is referred to as the RTU Master ICD file. The RTU Configuration

Tool will read this file and the user will select the required data

objects and associate them with internal RTU references (digitals,

analogs, alarms and controls).

The main activities were to identify the set of logical nodes

incorporating the ones required the FPP project, the ones that

could be defined as standard for UK Power Networks’ substations

and potential additional requirements for future applications. In

order to identify the overall requirements, the project engaged

with internal stakeholders. IEC 61850 training sessions and

workshops were carried out and will be carried out to disseminate

and develop IEC 61850 knowledge through operational teams.

The RTU Configuration Tool will output an SCL file of type .CID which

contains the configured IED information including the configuration

of data sets and report control blocks which the RTU uses to report

input data. The overall process is described in Figure 4.

Manufacturer

System Configurator

Master ICD

Updated Master ICD

*.ICDANM

4

1

1

2

3

4

FPP creates the Master .ICD with LN type templates

GE IED Configurator creates CID for specific substation with instantiated LN and LD from template

The specific CID is used by the System Configurator to create SCD for ANM system

TBD - in case of updating a Master LN type the CID be updated ‘easily’ with the new type

Specific.CID

GE IED Configurator

2

*.SCD

3

ICD Editor

Figure 4: Data engineering process for RTU configuration

*.ICD


| 29

IEC61850conformanceandcertification

One of the FPP project requirements is that any field device

using IEC 61850 protocol for the purpose of the project needs

to be certified. The IEC 61850 conformance blocks shown in

Table 3 have been identified to cover the FPP requirements.

The smart devices and applications were successfully

certified by independent third party assessors against the

FPP requirements.

Table 3: IEC 61850 conformance blocks for FPP

1: Basic Exchange Ass1, Ass2, Ass3, AssN2, AssN3, AssN6

AssN4, AssN5

Srv1, Srv2, Srv3, Srv4, Srv5, SrvN1abcd, SrvN4 Srv6, Srv7, Srv8, Srv9, Srv10, SrvN1e,

SrvN1f, SrvN2, SrvN3

2: Data Sets Dset1, Dset10a, DsetN1ae Dset10b, DsetN1b, DsetN16

5: Unbuffered Reporting Rp1, Rp2, Rp3, Rp4, Rp7, Rp10, Rp12 Rp5, Rp6, Rp8, Rp9, Rp11, RpN5,

RpN1, RpN2, RpN3, RpN4 RpN6, RpN7

6: Buffered Reporting Br1, Br2, Br3, Br4, Br7, Br8, Br9, Br12, Br14 Br5, Br6, Br10, Br11, Br13, BrN6, BrN7

BrN1, BrN2, BrN3, BrN4, BrN5

13: Time sync Tm1, Tm2, TmN1 Tm3, TmN2

ConformanceBlock Mandatorytestcases Conditionaltestcases


30 |

DNP3(DistributedNetworkProtocol)

DNP3 is also an open standard communications protocol

implemented for two applications in FPP project. In UK

Power Networks DNP3 is currently used by SCADA application

ENMAC to communicate with remote outstations or RTUs. As

ENMAC does not yet support IEC 61850 standard, ANM uses

the DNP3 protocol to communicate with it. In this case the

ANM acts as a DNP3 slave to ENMAC acting as a DNP3 master.

The second implementation of DNP3 in the FPP project is

at the substation level to communicate with optical Current

Transformer (CT) provided by Powersense. The optical CTs

are used to obtain current measurements for overhead lines

where CTs were not easily available. In this case the Optical

CTs act as a DNP3 slaves to the GE T5500 RTU which is acting

as a DNP3 master. This further demonstrates flexibility of the

FPP architecture by concurrently supporting existing and new

protocols at different levels.

SNTP(SimpleNetworkTimeProtocol)

Precise time clock synchronisation is an important requirement

for real time applications like ANM. Time synchronisation

provides common reference point for communicating devices

and allows accurate correlation of network events. As defined

in IEC 61850-8-1, SNTP is used for time synchronisation

in the FPP architecture for all communicating devices. At

operations level, the ANM system uses SNTP to synchronise

its time clock with the UK Power Networks’ master clock

at the control centre. However, this facility is not available

at the station level so, SNTP time server functionality was

developed within the GE T5500 RTU by the FPP project. The

RTU uses a local GPS receiver to maintain its internal time

clock and further allows FPP smart devices to subscribe to its

time service, that ensures that all system components and

measurements are time synchronised.


| 31

Data optimisation4.3The IEC 61850 standard was originally developed for internal

substation applications utilising high speed communications.

However, the FPP project is stretching the capabilities of the

standard by applying it over a wide geographic area over a

given bandwidth of a radio mesh technology. Hence, the data

communications need to be carefully optimised considering

the impact on the data loading on the radio mesh network

under the anticipated stress conditions such as communications

outage, disaster event, network congestion etc.

Initial lab tests carried out by Smarter Grid Solutions

indicated ANM data utilisation of 30 Kbits per second based

on connection of 6 Generator controllers and all FPP smart

devices as shown in Table 4.

Table 4: FPP data usage estimation

Generator Controller (local Generator Controller) 6 1 26,400

RTU ( Remote Terminal Unit) 2 3 3,387

AVC (Automatic Voltage Control) 2 5 480

QBCS ( Quadrature-booster Control system) 1 5 240

Dynamic line rating 4 600 8

Weather Station 1 600 2

Totalexpecteddatautilisationforallsmartdevices 30.5kbps

SmartDevices(Servers) Devicecount Reportperiod(secs) Datautilisation(bps)


32 |

However the testing carried out on RF mesh networks

showed data throughput of 25 kbits per second based on

the worst case scenario of 3 RF mesh hops. As illustrated

by the Figure 5 as the generator connections increase, the

data utilisation will also increase resulting in a progressive

degradation of network performance. This clearly highlighted

a requirement of optimising the utilisation of IEC 61850 data

over the RF mesh network.

Figure 5: Data traffic and DG connections

Date

Loa

ding

(kb

ps)

160

140

120

100

80

60

40

20

0

Number of Generators

15 25 35

Dataloading(kbps)

5 10 20 30


| 33

The FPP team organised a brainstorming workshop with

Silver Spring Networks, Smarter Grid Solutions and DNV KEMA

to identify possible areas of improvement to the application

and communications network. Extensive lab tests were also

carried out in the UK Power Networks lab to understand and

analyse the behaviour of ANM traffic over different settings

and scenarios. This process has already identified some key

enhancements which have been subsequently tested and

implemented. As part of the FPP trial phase, further test cases

will be undertaken with both real and simulated devices on

the trial network to continue fine tuning of the network.

Another objective of this exercise was to identify the tipping

point of the existing FPP communications infrastructure, which

means identification of potential scenarios that will require

certain upgrade or modification of existing equipment. The

following are the key areas for enhancement:

• The initial design of 1 second Integrity poll by ANM used in

table 4 has been found to be unnecessary and impractical

for FPP. Hence, reporting of data change only by exception

from the field devices has been implemented to reduce

the traffic load.

• The lab testing showed ANM sent five keep alive messages

per second. The ANM has been reconfigured to significantly

reduce the rate of generation of keep alive messages.

• Adoption of efficient techniques during IEC 61850 data

modelling to reduce the size of data payload generated on

each transaction.

• Various actions have also been identified to fine tune the

behaviour of ANM client and servers.

The data optimisation has been key in achieving a balance

between the cost of the communications infrastructure to be

deployed, the actual data communications requirements of

the various components and the performance of the overall

solution in terms of latency. This work will continue during

the trials and it will be critical in determining the actual traffic

requirements for the overall solution, these will be become

available during the trials phase.

5Smart Devices


| 35

The FPP technical solution implements smart devices from

various vendors to address and manage specific existing or

anticipated network constraints and operational limitations

of the network that either restrict DG connections or are

introduced by the connection of DG. The range of smart devices

includes: Quadrature-booster and associated control system,

Dynamic Line Rating system, Automatic Voltage Controllers,

upgraded Remote Terminal Units and novel protection relays.

This section outlines the concept, design, installation, testing

and commissioning of the smart devices. For clarity, the

Generator Controller device will be presented in the section 6

related to the ANM. At the time of bid award the project also

expected to deploy Frequent Use Switches, these are no longer

required as the same trials can be delivered using business-as-

usual equipment (ring main units).


36 |

Quadrature-booster and Quadrature-boosterController System (QBCS)

5.15.1.1Concept

The QBCS is used to control an on-load tap changer connected

within a Quadrature-booster, which has been deployed to

adjust the phase angle within a circuit that increases the

impedance of an individual line. This Quadrature-booster has

the aim of transferring power onto the lesser utilised of two

parallel circuits. The QBCS controls this process by calculating

the active power flow in the two parallel circuits and setting

the TAPCON 260 to adjust the power flow to achieve optimal

power sharing between the two circuits. The deployment

of the Quadrature-booster within the FPP project provides a

demonstration that improved balance between the circuits

would allow additional aggregate power flow capacity

headroom of approximately 10MW.

5.1.2Designandinstallation

The Quadrature-booster is installed on the Downham Market

teed circuit at Wissington British Sugar substation 33kV end.

Appendix 2 shows the simplified single line network diagram

with the Quadrature-booster installed in the Downham

Market teed circuit.

Under standard running arrangement the Downham Market

teed circuit is loaded approximately twice as much loading

as on each of the Northwold and Southery circuits. The

maximum power flow limits on the Wissington outgoing

33kV circuits are laid down in the Connections & Use of

System Agreement (1997). Excess power flow beyond the

maximum limit is undesirable since it will over-stress system

components and cause damage to the Downham Market

teed circuit.

The QBCS, which consists of a TAPCON 260 relay manufactured

by Maschinenfabrik Reinhausen (MR) and designed and

installed by Fundamentals Ltd, operates in the four modes:

1.Automaticmode(AUTO): The power flow is automatically

controlled by TAPCON 260 relay in accordance with set

parameters. The QBCS settings cannot be changed in

automatic mode. This operation can be enabled/disabled

both locally and remotely.

2.Manualmode(MANUAL): In manual mode, no automatic

controls occur. The motor drive unit can be controlled via

the QBCS operating panel or the front TAPCON 260 relay

panel and via SCADA.

3.Localmode(LOCAL): There is no active management by

the QBCS in this mode.

4.Remote mode (REMOTE): In remote mode commands

from Control via ENMAC are executed. In this mode,

manual operation of the RAISE, LOWER, MANUAL and AUTO

keys is disabled. This is accessed via hardwired inputs from

ENMAC via SCADA.

The Quadrature-booster operates in single mode – no

parallel operation. Control of the Quadrature-booster OLTC

is individually selectable from either “Remote” control from

ENMAC via SCADA or “Local” from the QBCS display.

The QBCS is connected to the substation RTU with hard

wires to communicate with the UK Power Networks SCADA

using legacy communication network. The QBCS relay

communicates also with the ANM system using IEC 61850

via the FPP substation LAN and FPP communication platform.

The QBCS relay synchronises its time clock with UK Power

Networks time service provided by substation RTU using SNTP

protocol over the substation LAN. This architecture ensures a

common time reference is achieved for all FPP devices.


| 37

5.1.3Testingandcommissioning

The factory acceptance testing for the QBCS TAPCON 260 relay

was successfully completed in May 2013, at Fundamentals’

factory in Swindon. When the Quadrature-booster was

installed a cold commissioning test was completed, which

consists of a number of off-load tests designed to confirm

correct installation and configuration of the system prior to

the final connection, commenced in early June 2013. The

final commissioning for the project was undertaken and

the Quadrature-booster was energised in July 2013. When

the Quadrature-booster and the QBCS were commissioned

on site, the final site integration was undertaken to ensure

that the equipment was able to send information to the ANM

system. The QBCS was connected to the LAN using fibre links

and the local connectivity was tested. At first stage a 61850

Client Simulator was used to interact locally with the QBCS.

The Client simulator were able to connect the QBCS, acting

as an IEC 61850 Server, to read information from the relay

and to subscribe to identified data such the power of the two

lines or the tap position. Then the relays were connected to

the RF mesh infrastructure to run end-to-end tests with the

ANM system. During the tests, the power of the lines and

tap position were successfully sent to the centralised system.

The results of these tests have been captured into the site

commissioning report to provide the necessary evidence of

the successful integration of the Dynamic Line Rating into the

FPP technical solution.


38 |

Dynamic Line rating5.25.2.1Concept

The aim of Dynamic Line Rating technology is to utilise the

spare capacity in the network by calculating the real time

thermal rating of power lines. The FPP project is further

exploring the application of dynamic line rating technology

in combination with the ANM system and open standards IP

communication network by removing seasonal export limits to

allow generation output to match available network capacity.

In essence, the main function of the Dynamic Line Rating in

FPP project will be to calculate and provide dynamic ampacity

values for 33kV overhead lines to the ANM system using

real time measurements of wind speed, wind direction and

ambient air temperature obtained from weather stations.

Four constraint locations (refer to Table 1 for locations) were

identified within the FPP trial area where implementing

Dynamic Line Rating system can release additional headroom

for accepting power export from new generation connections.


The dynamic line rating devices are installed in three

substations. Two dynamic line rating devices were installed

at Farcet primary substation, one device at Funthams Lane

primary substation and the final device at March Grid

substation. The dynamic line rating solution for FPP project is

provided by Alstom’s MiCOM P341 relay. A compact weather

station WS501-UMB (Lufft) is installed locally which provides

dynamic weather measurements to MiCOM relay. The dynamic

line rating solution also consists of a data logger Bitronics M871

which stores all the weather measurements and ampacity

values as well as phase current values where available.

5.2.2.1 Dynamic line rating functionality

The primary function of dynamic line rating is to calculate the

real time ampacity rating of the overhead line from some

or all of the local weather measurements received from the

weather station. The calculations for FPP project are based

on the algorithm specified by CIGRE 207 standard which

are provided by specific programmable scheme logic within

the MiCOM P341 relay. A data logger has been included to

enable disturbance, waveform and trend recording features for

analytical purposes.

5.2.2.1 Dynamic line rating architecture and communications

The MiCOM relay communicates to the ANM system using IEC

61850 via FPP substation LAN and FPP communication platform.

The ANM system stores the data sent by the MiCOM relay into the

UK Power Networks data historian. All the detail of the MiCOM

relay data are also stored in the data logger for post-analysis.

These data will only be accessed locally due to the risk of data

congestion from transferring large data files. Both the MiCOM

relay and datalogger synchronise their time clock with UK Power

Networks time service provided by GE T5500 RTU using SNTP

protocol over the substation LAN. This architecture ensures a

common time reference is achieved for all FPP devices.

As illustrated in the architecture diagram in Figure 4, the

weather station provides weather data to both MiCOM relay

and datalogger via analogue interface. MiCOM relay also

provides calculated data to the datalogger for historic analysis

via analogue interface. In the context of Figure 4, the physical

interface between FPP network comprising of the smart devices

and the ANM and the DLR relay is the substation LAN switch

which is also the gateway to the communications platform.


Following the manufacture of the dynamic line rating system, a

factory acceptance test was completed to verify the satisfactory

operation of the system prior to dispatch for installation. The

factory acceptance tests focused on the correct operation of the

dynamic line rating relay (MiCOM P341) and ensuring that this

operated within the design limits imposed on the relay. This

was achieved by simulating inputs from the weather sensor

and assessing the outputs of the relay to those expected.


| 39

Following the successful installation of the equipment, final

testing and commissioning was undertaken to verify the

correct operation of the Dynamic line rating Relay (P341)

and the data logger (M871). An overview of this testing and

commissioning is described as follows:

• Dynamic Line Rating relay: The settings within the

dynamic line rating relay (P341) were verified against

those developed during the design phase of the project.

Data generated by the weather station was then collected

through the relay and used to calculate the ampacity using

the CIGRE standard. This calculated ampacity value was

compared against the ampacity value generated within the

relay to check its validity.

• Data logger (M871): The information recorded within

the data logger has been checked to verify that it aligns

with the information generated by the weather station and

dynamic line rating relay.

When the dynamic line rating devices were commissioned

on sites, the final site integration was undertaken to ensure

that the equipment was able to send information to the ANM

system. The dynamic line rating devices were connected

to the LAN using fibre links and the local connectivity was

tested. At the first stage a 61850 Client simulator was used

to interact locally with the dynamic line rating devices. The

Client simulator was able to connect to the dynamic line rating

systems, acting as an IEC 61850 Server, to read information

from the relay and to subscribe to identified data such weather

information or ampacity. Then the relays were connected

to the RF mesh infrastructure to run end-to-end tests with

the ANM system. During the tests weather information and

ampacity were successfully sent to the centralised system.

The results of these tests have been captured into the site

integration test schedules to provide the evidences of the

successful integration of the dynamic line rating into the FPP

technical solution.

Figure 6: Dynamic line rating architecture diagram

Dynamic Line Rating System - Alstom

5

32

1

6

4

CTs P341

M871

Flexible Plug and Play Network

Weather station

Key

Current measurements

Weather station analogue output to data logger M871

Weather station analogue output to DLR P341

DLR P341 analogue output 4-20mA to data logger M871

Fibre link to FPP Network (IEC61850 and SNTP)

Ethernet link to FPP Network (SNTP)

1

2

3

4

5

6


40 |

Automatic Voltage Controller (AVC)5.35.3.1 Concept

The high penetration of DG around March Grid significantly

changes behaviour of the distribution network around that

area. High volumes of generation connecting onto the network

affects the voltage profile on the distribution network, and

possible unacceptable voltage rise at the point of common

coupling (PCC). Like other distribution networks, the original

design does not consider bi-directional power flows, voltage

rise contributions from DG, and other associated impacts. As

a result standard voltage regulation strategies are unable to

satisfactorily deal with these problems. Modern novel solutions

are required to allow bi-direction power flows with voltage

regulating strategies equipped to handle the effects of DG on

system voltage profile. The aim of AVC trials is to provide an

innovative automatic voltage control scheme integrated with

ANM and could help in addressing voltage issues caused by DG.

The SuperTAPP n+ relay from Fundamentals has recently been

approved by UK Power Networks for use on the distribution

network. The FPP trial aims to build on this success and

address, among other things, the following:

• The benefits associated with the interaction of SuperTAPP n+

with other smart technologies, such as the ANM.

• Identifying the voltage headroom provided through the use

of the SuperTAPP n+ within the FPP project area, specifically

at March Primary where a cluster of DG is connecting.

The trials will include:

• Prove communication of SuperTAPP n+ with ANM using IEC

61850 Standard.

• Assess the possible interaction between the local and

centralised voltage regulation strategy.

• Remote measurement of voltage using SuperTAPP n+

5.3.2 Design and installation

The FPP has installed a set of SuperTAPP n+ relays at both

March Grid and March Primary (refer to single line drawing in

Appendix 3) as described in Figure 7:

Figure 7: Simplified SuperTAPP n+ Connection

Key

On Load Tap Changer

OLTC

X X

VTARG

VG

VLDC

SuperTAPPn+ Relay

Feeder 1

Feeder 2

IFG

IL1

IG

IL2

VVT I

TL


| 41

The existing AVC schemes at March Grid and March Primary

are equipped with SuperTAPP and MVGC01 relays respectively.

These have been replaced with Supertapp N+ which will

provide more accurate voltage control at substation level and

will also interface with the ANM system via the IEC 61850

protocol.

March Grid 132/33kV substation comprises 2 x 45MVA grid

transformers fed at 132kV by two overhead line circuits from

Walpole Grid Supply Point and interconnected to Peterborough

Power Station. The 132kV circuits are teed to Walsoken Grid

and Peterborough Central Grid. The simplified single line

drawing is shown in Appendix 3.


The AVC system was visually inspected and electrically tested

prior to energising, with functional tests undertaken to confirm

that the scheme is operating as required. The scheme was

then connected with UK Power Networks’ SCADA and tested

to confirm that alarms. Indications and controls operate as

designed.

Final site integration was undertaken to ensure that the

equipment was able to send information to the ANM system.

The AVC devices were connected to the LAN and the local

connectivity was tested. At first stage a 61850 Client simulator

was used to interact locally with the AVC devices. The client

simulator was connected to the AVCs, acting as an IEC 61850

Server, to read information from the relay and to subscribe

to identified data such voltage measurement or tap position.

Then the AVCs were connected to the RF mesh infrastructure to

run end-to-end tests with the ANM system. During these tests

the voltage information and tap position were successfully sent

to the centralised system. The results of these tests have been

captured into the site integration test schedules to provide the

evidences of the successful integration of the AVCs into the FPP

technical solution.


42 |

Remote Terminal Unit (RTU)5.45.4.1Concept

In existing distribution network architecture, Remote Terminal

Units (RTU) are installed into the substations (grid, primary and

also some distribution substations) in order to provide network

control and monitoring functionality by communicating with

the SCADA system. As part of business as usual UK Power

Networks install RTUs delivered by GE Power Conversion from

its product line T5500, which uses the a legacy communication

method that relies on satellite links.

As part of the FPP architecture, the primary function of the

RTU is to collect relevant substation data and communicate this

data to the ANM system. This function for FPP is additional

to the RTU’s normal functionality unrelated to FPP. The main

innovation introduced by the project is the use of the IEC 61850

standard to enable this communication outside the substation

via the RF mesh.

The IEC 61850 is a standard widely used to implement new

generation of electrical substation, which allows for a design

scalable architecture. This choice has also been driven by the

necessity to separate the flow of information transmitted to

the SCADA system which uses a DNP3 protocol. Indeed all

the RTUs also continue to communicate directly with ENMAC

via a separate communications port on the RTU and separate

communications infrastructure independent of the FPP Wide

Area Communications Infrastructure


FPPrequirementsfortheRTUupgrade

One of the key requirements of for the RTU is the ability to

provide all data items to the ANM system, although the RTU is

configurable such that only data relevant to the ANM system

are provided. Also the RTU has the capability to receive data

items from the ANM system, although the RTU is configurable

such that only data relevant to the RTU are provided.

The RTU collects information from the new devices introduced

as part of the FPP project, for the purposes of providing

this information to ENMAC via the existing RTU to ENMAC

communication links.

The RTU utilises at a minimum, the following communications

protocols (over and above those protocols already in use

for communications between the RTU and other connected

systems/devices such as ENMAC):

• IEC 61850 is used for communications between the RTU

and ANM. The RTU is configured as an IEC 61850 server.

In order to optimise limited bandwidth available on the

Wide Area Communications Infrastructure, data volumes

and packet sizes are optimised in terms of minimising the

overhead introduced by the protocol itself. This is likely to

require the configuration of report control blocks in the RTU,

and buffered and/or unbuffered reporting from the servers

being triggered by exception.

• DNP3 over IP is used for communications between the RTU

and local devices. The RTU is configured as the DNP3 master.

• IEC 60870-5-103 is used for serial communications between

the novel protection relays and the RTU.

The RTU functions as a network time server, utilising SNTP as

defined in IEC 61850 to permit time synchronisation for all

smart devices connected on the substation LAN.

NewfunctionalitiesoftheupgradedRTU

To match with the required FPP specification, GE Power

Conversion implemented changes into its T5500 product.

More precisely the T5500 Processor firmware and the T5500

configuration tool have been upgraded to enable the RTU

to interface with an ANM system as required. The new

developments have implemented the following functionalities:


| 43

• IEC61850 Server: The interface to the ANM has been

designed to be by IEC 61850 protocol over a LAN. In this

design, the ANM acts as a 61850 Client and the RTUs

behave as IEC 61850 Servers. However, the existing RTUs

installed into the substations did not incorporate IEC 61850

Servers’ functionalities which have been developed by

GE Power Conversion for the FPP technical solution. For

the implementation, the IEC 61850 core ACSI services are

supported via MMS. The implementation does not require

supporting Sampled Values, Generic Object Oriented

Substation Events or Generic Substation Status Events.

The IEC 61850 server enables the ANM to subscribe to the

RTU and request data on change events from specified data

points. The server implementation uses predefined Report

Control Blocks (RCBs) for data transfer to client devices

(such as the ANM). In this respect, the server provides

the functionality required as configured using the RTU

Configuration Tool. Either one pair of RCBs per RTU or one pair

per Logical Device as required at the configuration time. In

this context, a pair will consist of a buffered RCB for reporting

digital inputs and an unbuffered RCB for analogue changes.

• IEC 61850 Server Configuration Tool: The T5500 reads

its configuration from an SCL file of type ICD and a data

mapping file, both generated by the T5500 Configuration

Tool. Any T5500 Digital or Analogue Input points which are

to be reported on the IEC 61850 interface are mapped to

Data Objects using a data mapping file. The configuration

process is detailed further in the report.

• SNTP TimeServer: The RTU acts as a time server, using

the GPS clock input available to it to maintain its clock,

and allowing other devices of the FPP technical solution to

synchronise with the time server in the RTU by sending it

SNTP requests. The SNTP server will respond to SNTP requests

from other devices on the network, or it can be configured

to broadcast or multicast the time at regular intervals. This

requirement ensures a common time reference is achieved

for all FPP devices.

The aim of these new developments is to provide necessary

measurements and indications from substation equipment to

ANM. This information enables ANM to determine the network

status and running arrangement for its calculations. As part of

the business as usual function, the RTU also interfaces with

some of the FPP smart devices such as QBCS, AVC and novel

protection relay to provide SCADA communications to ENMAC

as presented in the Figure 1. Also the RTU communicates

with Optical Current Transformer solution via DNP3 which

provides current measurement to ANM and other necessary

measurements to ENMAC.

RTUarchitectureandcommunications

The RTU communicates with ANM using IEC 61850 via FPP

substation LAN and FPP communications platform. However,

RTU is a critical component in the FPP architecture acting as

a common component shared between ENMAC and ANM. To

prevent any interference to SCADA network, the FPP network

will connect to RTU via a spare ethernet port which provides

both logical and physical separation between two networks.

• ENMAC communications: The RTU provides SCADA

communications to ENMAC via DNP3 protocol over SCADA

LAN and SCADA communications infrastructure. Ethernet

port 1 and a number of serial ports are used for SCADA

functionalities.

• FPPcommunications: The RTU communicates with ANM

via IEC 61850 standard using the spare ethernet port 2 over

FPP LAN and FPP communications platform. Ethernet port

2 will also be used for time synchronization service using

SNTP protocol and also to communicate with optical Current

Transformer solution via DNP3 protocol.


44 |


In total 12 RTUs were upgraded into 2 Grid substations and 10

Primary substations. The replacement of the technical panels

was completed following the business as usual procedure.

After the RTUs were installed and commissioned on the

relevant substations into the trial area, final site integration

was undertaken to ensure that the equipment were able to

send information to the ANM system. For each site, the RTU

was connected to the LAN using fibre links and the local

connectivity was tested. At first stage a 61850 Client simulator

was used to interact locally with the RTU devices. The client

simulator was able to connect the RTUs, acting as an IEC 61850

Server, to read information from the RTU and to subscribe

to identified data such digitals or analogue. Then the RTUs

were connected to the RF mesh infrastructure to run end-to-

end tests with the ANM system. Digital and analogue signals

were successfully sent to the centralised system. The results

of these tests have been captured into the site integration

test schedules to provide the evidences of the successful

integration of the RTUs into the FPP technical solution.


| 45

Novel protection relays5.55.5.1Concept

To improve the network capacity with regards to connection

of DG, it is important to allow the power flow to be in both

directions across the 132/33kV Grid transformers. At March

Grid the generation connections have reached its limit due the

reverse power flow restriction caused by the Directional Over-

Current (DOC) relays. The installation of a novel protection

scheme will provide a workable alternative to overcome the

limitation of the existing DOC protection.

Operationally within the business UK Power Networks’

standard for backup to the intertrip scheme on 132kV system

is DOC. With increasing DG connections reverse power flow

capacities, constrained by use of the DOC schemes, are

exceeded. Non-standard novel protection methods, use of

intertripping or generator constraining at risk period may

alleviate this problem.

Instead of applying DOC, novel protection relays that allow

full capacity of the transformers to be utilised for reverse

power flows can be used. Whereas Directional Negative Phase

Sequence (DNPS) may offer possibilities, this protection has not

been proven in practice. The FPP project therefore provides the

opportunity to install the DNPS in combination with Directional

Voltage Dependent Over-current (DVDO) in a ‘monitor/alarm

only’ mode. Two of these schemes have been installed for trial

at March Grid and Peterborough Central, and will operate in

parallel with the DOC.

The DNPS protection is limited to 132kV sites. It could however,

once accepted, provide a useful additional protection option at

other primary UK Power Networks sites.


The ‘main’ protection on the 132kV circuits from Walpole –

March – Peterborough Central is via pilot cables rented from

BT. At present UK Power Networks relies on DOC to back up the

intertripping function. The reverse power capacity is reached

well before the transformers reach their thermal or tap change


can be applied to the DOC protection. The DOC is normally

set at 50% of the transformer MVA rating. At both March and

Peterborough Central the DOC is currently set at 75%, which

the highest it can be set without losing its sensitivity and

becoming unable to detect faults.

The FPP project considered three alternative protection

philosophies available within Alstom’s P142 relay to replace

the DOC relays:

1.DirectionalVoltageDependantOvercurrent(DVDOC)on

the33kVside: This scheme only covers three phase faults

on the 132kV side. No issues identified.

2.Directional Negative Phase Sequence (DNPS) on the

33kVside: This scheme covers phase to phase and phase

to earth faults on the 132kV side. The studies show this

scheme is a potential solution, however its stability could

not be proven. The background “normal” and “abnormal”

levels of NPS for normal running and fault types that the

system must be stable for could not be determined. From

that point of view it is very difficult to determine whether

this scheme would remain stable without carrying out an

actual trial on the field and testing the scheme under real

network fault conditions.

3.NeutralVoltageDisplacement(NVD)onthe132kVside:

This scheme covers all types of the above faults, however it

will require set of CVTs on the 132kV side. Also this scheme

is non-directional, which means it needs to be slow enough

to discriminate against LV faults.

Based on the above it was recommended that a combination

of DVDOC and DNPS is used only for alarm but not for tripping.

These schemes initially will be monitored to assess their

performance against various faults and when a confidence


46 |

level is established then they could be adopted more widely

(or dropped as the case may be).

The relays are connected with the March Grid and Peterborough

Central RTUs to communicate with the UK Power Networks’

SCADA system via legacy communication links. Considering the

protection functionalities of these particular relays, there is no

need for data information exchanges with the ANM system.


The protection relays (P142) that were used by the project

are UK Power Networks approved protection relays and,

as such, were commissioned using the same process as for

a typical protection relay. The difference is in the additional

functionality being trialled, including the directional negative

phase sequence and voltage dependant overcurrent protection

philosophies.

For completeness, below is a high level overview of the

commissioning process undertaken:

The protection settings and scheme logic are downloaded

onto the protection relay and are then verified to confirm they

match those approved during the design process. The relay is

then secondary injected to check the drop off and pick up of

all of the protection functions. These include a pick up at 200A

with a time delay of 250ms for the directional negative phase

sequence protection and a reduction in the overcurrent setting

to a quarter of the default setting (1200A down to 300A) in

the event that the voltage drops to below 24kV for the voltage

dependant overcurrent. This is followed by functional checks

which verify the operation of the trip relays and the alarms

generated. Once complete, the protection settings and scheme

logic are checked once again to confirm there have been no

changes throughout the commissioning process.


| 47

Ring Main Units for network reconfiguration5.65.6.1Concept

The original scope of the project included a provision for two

frequent use switches to be deployed at a strategic location

on the 33kV overhead line circuits between Peterborough

Central and March Grid substations to enable seasonal running

arrangements and network reconfiguration to maximise the

DG connected onto the network. Since then, it was identified

that a reinforcement project currently being carried out at the

same strategic location that will utilise Ring Main Units (RMUs)

that it can deliver the same functionality. As such there was no

need to install the frequent use switches and this change to

the project was formally approved by Ofgem.


The RMUs are being installed to address an existing issue with

the loading of the 33kV circuits feeding Chatteris, Whittlesey

and Funthams Lane from March Grid.

The RMUs will provide the flexibility to run the network

with normally open points (NOPs) on the March Grid legs

at Whittlesey (see Appendix 4). This will enable Funthams

Lane and Whittlesey primary substations to be fed from

Peterborough Central and overcome the loading issue referred

to above. Through the ANM system, the project will monitor

the status of the March Grid legs of the Whittlesey RMUs, and

the setup will improve the network configuration changes by

increasing the flexibility to move load between Peterborough

Central and March Grid.

The control of the RMUs uses the legacy communication

network up to the UK Power Networks’ SCADA centre.

Distribution substations RTUs are installed to interface the

SCADA and the RMUs via DNP3 protocol. The ANM system

monitors the position of the switches so that its database

reflects the topology of the network (see section 7.1.3). The

switch position will be sent from the UK Power Networks’

SCADA to the ANM system using the existing DNP3 link

between the two environments. The feasibility of this solution

has been successfully tested during the acceptance tests of the

ANM production system. The solution will be configured when

the RMUs will be commissioned.

The 33kV Areva FBE RMUs are positioned on site, within

a self-contained GRP container. They are not electrically

connected, although are recorded on the asset management

tool as being available on site. Works on the cable circuits into

Peterborough Central are currently being carried out and to be

completed first (Q4 2013) before connecting the Whittlesey

RMUs (Q2 2014) to avoid the network being at risk, regarding

the removal of a 33kV link at Whittlesey Primary that cannot

be removed until the circuit work is complete.

6SmartApplications


| 49

As presented in the section 3, the network remaining capacity

into the FPP trial area is not sufficient to be able to offer firm

connections to new DG developers. Thus during the FPP trial,

the ANM will monitor and control the network so that the

existing remaining capacity can be fully exploited for new

interruptible connections.

ANM will involve the adoption of a platform and associated

autonomous software applications, from Smarter Grid

Solutions, to monitor and control the network in real time

to ensure it remains within its operating constraints. Within

the FPP project, several ANM applications will be deployed

including power flow management and voltage management

applications. The project also will also trial a thermal ratings

application which increases the capacity of the network when

weather cooling effects allow more power to be transferred,

particularly through overhead lines.


50 |

Design6.16.1.1ANMcomponents

The ANM system is composed of several centralised servers

communicating with the field devices as described in Figure 8.

CommunicationFrontEnd(sgscommshub)

The communication front end performs all data handling

and processing for the ANM system via a range of industry

protocols. The communication front end is configured to use IEC

61850, DNP 3.0 and OPC for the project. The Communication

front end is deployed on two Windows servers; one runs as

main and the other as a standby. The Communication front

end runs eXtremeDB, a real time database, and uses this to

communicate with the Application Server.

ApplicationServer(sgscore)

The application server is a modular, integrated, flexible and

scalable execution environment upon which the SGS smart

applications (i.e. Power Flow Management Application, Voltage

Management Application, Dynamic Ratings Application)

are deployed. The application server is deployed on two

Linux servers; one runs as main and the other as a standby.

The application server runs eXtremeDB and uses this to

communicate with the communication Front End.

PowerFlowManagementApplication(sgspowerflow)

The Power Flow Management Application manages the

power flow through chosen points on the network ensuring

it remains below specific thresholds. Power flow limits are

related to the thermal constraints of network equipment, such

as transformers or overhead lines. In order to perform power

flow management the current or power flow through the

chosen points on the network, also referred to as constraint

locations or ANM zone boundaries, are measured directly or

derived from the measurement of current or power flow at

other points on the network. Power flow management is

achieved by regulating the output of distributed generators

whose power export impacts on the power flow through

constraint locations on the distribution network.

VoltageManagementApplication(sgsvoltage)

The Voltage Management Application manages voltage at

chosen points on the network ensuring it remains within

specific thresholds. In order to perform voltage management

the voltage at the chosen points on the network, also referred

to as constraint locations, are measured directly or derived

from the measurement of voltage at other points on the

network. Voltage management is achieved by regulating

chosen parameters of controllable devices (i.e. in the case of

FPP, the real and reactive power of generators) associated with

the voltage constraints.

It is possible that the Power Flow Management Application

and the Voltage Management Application are controlling the

same device. In this case, there is an arbitration process which

decides on the priority action. For example, if both the Power

Flow Management Application and the Voltage Management

Application need to curtail a generator, the arbitration

compares the curtailment values and applies the lower of the

two values. At the time of writing, no such common devices

have been identified.

DynamicRatingsApplication(sgsratings)

The Dynamic Ratings Application monitors weather and

network information, and calculates the line power/ampacity

ratings for use by the Power Flow Management Application.

GeneratorController(sgsconnect)

The Generator Controller interfaces with and controls devices

connected to the network. It is deployed at each location of

a device controllable by the ANM system, receiving set-point

signals and transmitting these to the native control system of

devices under the control of the ANM. The generator controller


| 51

also implements an autonomous fail-safe mechanism in the

event of non-compliance, loss of communications or abnormal

operation. The generator controller includes a local Human

Machine Interface (HMI). Within this project, the Generator

Controller connects to generators and communicates that data

to the ANM via the IEC 61850 protocol.

Figure 8: General ANM architecture

sgs core (Main)

sgs power flow

sgs voltage

sgs ratings

sgs core (Standby)

sgs power flow

sgs voltage

sgs ratings

sgs comms hub (Main) sgs comms hub (Standby)

eXtremeDB

IP based WAN

IEC 61850 DNP 3.0 IEC 61850 DNP 3.0

IEC 61850 IEC 61850 IEC 61850 IEC 61850 IEC 61850

RTU (GE Power Conversion) sgs connect

Quad Booster

Current Transformer

DLR (incl Weather station)

Voltage Transformer

FUS AVC

DG

(vendor-specific com)

Weather station


52 |

Externalapplications

The ANM system passes data to two existing UK Power

Networks systems as shown in Figure 9:

1.TheSCADAsystem(ENMAC): ENMAC application provided

by GE Network solutions is the UK Power Networks

network management system. ANM exchanges data to

ENMAC application and presents itself as one of the RTU

objects to Control Engineers providing alarms, indications,

measurements and control functionality.

2.Thedatahistorian(PI):PI system provided by OSIsoft, is

the UK Power Networks central repository for operational

data and events including SCADA events. The ANM

communicates with PI using the Communication Front

End over the existing UK Power Networks communication

infrastructure. Any changes in the real-time database of

ANM are pushed to PI for storage.

The ANM system also receives control signals from ENMAC as

control engineers can enable/disable the ANM status of the

overall scheme, specific zones or specific generators.

Figure 9: Communication with external applications

sgs comms hub (Main) sgs comms hub (Standby)

IEC 61850 BACKHAUL

DNP 3.0 OPC DPN 3.0 OPC

DPN 3.0 OPC

ENMAC PI


| 53

6.1.2ANMRedundancyandFailsafeMode

Redundancy

The ANM hardware used for the trial is designed on “dual-

redundancy” principles; all hardware within the control centre

(i.e. the Communication Front Ends, Application Servers, and

the network switches) is duplicated such that the failure of

a single hardware item does not cause the ANM system to

fail. In addition to this dual-redundancy, each of the servers

is specified with its own internal redundancy: each server has

two power supplies, two network cards, multiple hard disks

configured as RAID 5 with a hot standby disk, two processors,

and multiple memory cards.

Communicationfailuresandfailsafemode

If communications fail between the ANM and one of the field

devices providing measurement point data (RTU, QBCS or

AVC), the ANM places the relevant measurement point out of

service. The associated generator controller is instructed to set

the corresponding DG into its fail safe state. The fail-safe state

is configured per generator and is either:

• A configured set point.

• A pre-configured schedule of set points.

Similarly if a communications failure is detected between the

ANM and the generator controller, the generator controller

moves to a failsafe state and will take one of the following

actions, depending upon the configuration of the generator

controller:

• Issues each connected generator with a pre-configured fail

safe set point or

• Issues set points to each connected generator as dictated by

a pre-configured fail safe schedule.

Meanwhile the Power Flow and Voltage Management

Applications exclude the generator from all power flow

calculations. No control actions are attempted by either Power

Flow Application or Voltage Management Application on this

generator controller.

The communication failed state is entered by the generator

controller when communication has failed for a configurable

amount of time. The fail safe is specific to each generator

controller.

If a communication failure occurs with the dynamic line rating

or the weather station, the rating application is designed to

cope with missing data and uses the best data available to

provide a rating. In the event of the loss of all live data it uses

seasonal ratings which are stored within the ANM database.

6.1.3Networkrunningarrangements

In order to configure the ANM applications to manage the

FPP network, the network running arrangements have to be

known. There is a standard running arrangement (the normal

running arrangement) and this has been used during the power

systems analysis carried out by Smarter Grid Solutions. The

ANM applications can manage multiple running arrangements

if these are pre-defined and the relevant analysis completed.

The ANM will monitor the network topology using the status

of ring main unit and circuit breaker via information passed

from the RTUs or ENMAC.

A change in position of the switches entails dynamic

reconfiguration of the relationships between the Measurement

point and the Distributed Generators for the Power Flow

Management Application and Voltage Management

Application. When the ANM system recognises a change

in network configuration, the Power Flow Management

Application and Voltage Management Application read in the

configuration data (i.e. Measurement Points and Generators)

for the specific network arrangement and immediately use

these to manage the network.


54 |

6.1.4Productionplatform

ProductionANMHardware

The production ANM hardware (Figure 10) consists of the

following items:

• 2 x Application Servers;

• 2 x Communication Front Ends;

• 4 x Generator Controllers with dedicated HMI’s;

• 1 x Weather Station (a MetPak™ Pro Weather Station plus a RTU).

The ANM servers are installed into the UK Power Networks’

control centre and are managed according business as usual

rule by operational teams.

Figure 10: ANM production platform for site acceptance test

UKPN Network

Standalone Weather station site

Weather station

BrodersenRTU32

NetworkMeasurements

UKPNRTU

DLR

AVC Relay

QBCS

Generator Control System

BrodersenRTU32

SGSconnect

ANM DG Site x

AB Panel View

LocalUI

sgs connect panel

MOBUS

sgs core 1

sgs core 2

sgs comms hub 2HP

sgs comms hub 1HP

HP

HP

UKPN Switch

UKPN Switch

UKPNServer/RTU

UKPNENMAC

UKPNServer

PI Historian

Central Rack

DPN3.0

OPC

HMI Data

IEC61850


| 55

Testing and commissioning6.2The FPP project required the testing of the two sets of ANM

platform: Pre-production and Production. For each of these sets

of ANM system there were two test stages: factory acceptance

test and site acceptance test.

Factory acceptance tests were performed to test all functional

and non-functional elements of each sub-system component.

The factory acceptance tests were carried out on both the

pre-production and production sets of hardware, with test

simulators being used during the tests.

The site acceptance test of the ANM pre-production hardware

were carried out within an FPP-wide pre-production

environment (the integration laboratory) set up by UK

Power Networks which includes the relevant test simulation

equipment. Site acceptance test of the ANM Production

hardware was carried out once all the production equipment

had been installed in the live environment.

In order to ensure that all the relevant tests have been carried

out, the Acceptance Test Specification (ATS) for the ANM

system was defined. This document described a suite of tests

used to ensure that all functionality declared in the Functional

Design Specification is adhered to. It details the individual tests

performed at each stage of acceptance testing.

6.2.1Testprocedure

For all the acceptance test procedure, three test stages were

performed:

1.Hardwaretests: these tests ensure that all target hardware

is fit for purpose without testing any application logic. These

tests are performed at factory acceptance test and site

acceptance test for pre-production and production.

2.Data Transfer tests: Data transfer tests validate

communication and data exchange between all sub-system

elements with application logic loaded. Tests performed at

factory acceptance test ensure that all Generator Controller

instances and the other IEDs can communicate with the

Communication Front End at the data transfer level. The

tests performed at the site acceptance test validated the

data transfer between the target hardware not available

during the factory acceptance test. The data transfer tests

validate the capability of the ANM system to interoperate

with the external components mainly using IEC 61850 but

also other protocols (DNP3 and OPC).

3.End-to-End tests: Upon successful completion of all data

transfer and hardware tests the ANM scheme can be tested

as a single unit. Testing the functionality of the scheme as

a whole involves exercising core logic and observing how

all sub-system components interact with one another, from

end-to-end. All end-to end tests are performed at factory

acceptance test; most are repeated at site acceptance test.

6.2.2Testsimulation

During the acceptance tests, one of the key challenges was the

ability to simulate the different component of the architecture.

For this purpose a test simulator was used for the factory

acceptance test/site acceptance test of both pre-production

and production. This is provided on Smarter Grid Solutions

hardware and provides simulation of power system quantities,

allowing ANM applications to be tested against an environment

similar to that expected in production. The simulation functions

provided by the test simulator are described below.

• Measurement Point Simulation: The test simulator

includes a measurement point simulation algorithm for

each measurement point. This simulates the current and

voltage measurement at each measurement point. The

effect of firm generation on current and voltage measured

at measurement points is simulated. Varying the firm

generation represents a combination of firm generation and

load and is a value which can be manipulated manually to

vary the current and voltage at the measurement point. The


56 |

simulation function may be enabled or disabled to allow

tests to be carried out as required.

• Generator Simulation: The test simulator simulates the

feedback of the generation control system and input it

to Generator Controller. This tool simulates the output of

multiple DGs and provides the following functionality:

• Circuit Breaker Controls and Indications: This provides an

indication of the circuit breaker position based a trip or

close signal from the ANM system.

• DG Output: This simulates the output of the generator

based upon the ANM target set-point. A ramp algorithm

was used to permit a gradual change of the export power

towards the set-point.

• Communications: This allows communication between

Generator Controller and Communication Front End to

be stopped or started. This is used whilst testing the

response of Power Flow Management Application,

Voltage Management Application and Dynamic Ratings

Application to a loss of communications to Generator

Controller and other field devices.

• ExternalSystemSimulation: The test simulator includes

a DNP3 Client that simulates data transfer to/from the

UK Power Networks’ SCADA system (ENMAC). The test

simulator includes an OPC Client that simulates data transfer

to the UK Power Networks Data Historian (PI).

• SmartDevicesorIEDsSimulation:The test simulator includes

a 61850 server test harness which allows the simulation of

data transfer to/from any of the IEDs. The IEDs are AVC relays,

the QBCS, dynamic line rating devices and UK Power Networks

RTUs. For each device, the simulation includes 61850 data sets

and associated Report Control blocks.

6.2.3Results

The acceptance test activities related to the ANM system started

in February 2013 by the factory acceptance test of the pre-

production platform. All the tests described in the acceptance test

specification document and compatible with the architecture of

the pre-production platform were passed successfully.

The site acceptance test of the pre-production platform was

then completed forming the core element of the integration

laboratory and providing the evidence to the successful

delivery of pre-production interoperability test for FPP’s smart

applications as required for SDRC 9.4.

The ANM production servers were then installed at the

UK Power Networks’ control centre. In order to proceed most of

the test remotely, dedicated and secure links have been put in

place between the Smarter Grid Solutions offices in Glasgow,

the UK Power Networks Control Centre and the UK Power

Networks London offices.

For the purpose of the final site acceptance tests, two

generator controllers were temporarily installed in the trial

area into two substations (March Grid and Chatteris Primary).

The site acceptance test of the Production platform was

completed in July 2013 which met the requirement for the

successful installation and commissioning of production smart

applications as part of the evidence for SDRC 9.4.

| 57 Flexible Plug and Play Quadrature-booster Report – SDRC 9.8 | 57

7Next steps


58 |

The FPP technical solution was successfully commissioned on

the distribution network in September 2013 in readiness for

the transition of the prospective FPP trial phase running to the

end of 2014.

The telecoms platform was successfully delivered in March

2013 and further work has subsequently been undertaken to

understand the performance and limits of this technology with

integration of various components of the overall solution. The

on-going work on optimised use of IEC 61850 data over the

Radio Frequency Mesh communication infrastructure under

various system conditions, is a key area for innovation and

development.

The delivery of Quadrature Booster transformer in July 2013

generated significant learning for the business in both design

and commissioning areas. Further knowledge will be captured

during the trial phase when it will be closely monitored during

its operation in the live network.

Significant knowledge was generated as part of the design,

commissioning and testing process of all the smart devices

and the smart application. Key learning has been produced in

the areas of implementing an interoperable solution based on

IEC 61850. The learning generated will support and improve

any further roll-out and evolution the FPP technical solution.

In order to address the gap in skills and knowledge in the IEC

61850 standard within UK Power Networks, the FPP project has

started engaging and training relevant internal stakeholders

and will continue during the FPP trial phase.

One of the challenges of the project turned out to be resolution

of protection issues relating to the implementation of various

FPP solutions. This has enormously engaged both FPP team

and the business throughout the process stretching the

boundaries of our technical expertise.

Despite the utilisation of some proven technologies, FPP

project has attempted to gain further knowledge on their

capabilities by changing the approach on their operation and

integration with other solutions. ANM, Dynamic line rating and

Automatic Voltage Control will be those solutions generating

learning of that nature.

Trial plans are currently being developed in order to test the

main functionalities of the solution under various operational

scenarios and conditions. These trials will take place during 2014

in parallel with SDRC 9.6 (Implementation of active voltage

management with the trial area) and SDRC 9.7 (Implementation

of active power flow management within trial area).

The learning will be disseminated through a learning report, a

dissemination event, academic papers and bilateral engagement

with DNOs and interested parties and it will be shared via the

project website (www.flexibleplugandplay.co.uk).

8Appendices


60 |

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Bury

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rid

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es

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rbor

ough

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erSt

atio

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ttle

sey

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ham

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Ort

on

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ough

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ral

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33 k

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x 60

MVA

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1

12 1

1 2

1

Sou

ther

y

1

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12

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km

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erbo

roug

h Ce

ntra

l - M

arch

Grid

)

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L W

(S

)

5MW

G

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ch P

rimar

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etw

ork

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sing

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ener

ator

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21

2

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dem

and

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mer

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5W

inte

r 20.

5

0.5

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216

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sing

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C

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fham

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ket

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oors

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s Ly

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s Ly

nnPr

w S

tn

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tLa

ne

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soak

enG

ridG

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bech

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ay

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216

MW

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116

MW

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km(W

also

ken

- Lev

erin

gton

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Leve

ringt

on

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hirn


1

23

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pole

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(61)

MVA

Farc

et

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12M

W

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W

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110

MW

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214

MW

Bury

1 2

No.

27.

2MW

No.

12M

W


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ell

Lake

s En

d1

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lepo

rt12

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ch G

rid13

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kV

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45 M

VA

EML

W (S

)59

(43)

MVA

GT1

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12

1020

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ch11

kV



18.3

km

(Mar

ch G

rid -

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ham

s La

ne T

1)

12

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teris

11 k

V

Chat

teris

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ary

11 k

V N

etw

ork

1

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man

ches

ter

Woo

dwal

ton

Brin

gton

RA

F A

lcon

bury

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tingd

on G

rid

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es

Pete

rbor

ough

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erSt

atio

n

CCG

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0MW

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21

21

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ttle

sey

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ham

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Ort

on

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1

3

1

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rbor

ough

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ral

132/

33 k

V2

x 60

MVA

1 2 3

1

12 1

1 2

1

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ther

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2 1

12

P49

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km

(Pet

erbo

roug

h Ce

ntra

l - M

arch

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)

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L W

(S

)

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G

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ch P

rimar

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kV N

etw

ork

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sing

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ener

ator

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21

2

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dem

and

MW

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mer

14.

5W

inte

r 20.

5

0.5

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0.5

216

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sing

BS

C

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fham

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ton

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old

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ket

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on

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oors

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s Ly

nn G

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all

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s Ly

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w S

tn

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tfas

tLa

ne

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soak

enG

ridG

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bech

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ay

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216

MW

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116

MW

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km(W

also

ken

- Lev

erin

gton

T2)

Leve

ringt

on

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hirn


1

23

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pole

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ough

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h G

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NE

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r S tb

tee

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ough

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th G

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ough

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ral

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1 kV

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W (S

)73

(61)

MVA

Farc

et

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12M

W

16M

W

No.

110

MW

No.

214

MW

Bury

1 2

No.

27.

2MW

No.

12M

W


Upw

ell

Lake

s En

d1

Litt

lepo

rt12

Mar

ch G

rid13

2/33

kV

2 x

45 M

VA

EML

W (S

)59

(43)

MVA

GT1

GT2

12

1020

Mar

ch11

kV



18.3

km

(Mar

ch G

rid -

Funt

ham

s La

ne T

1)

12

Chat

teris

11 k

V

Chat

teris

Prim

ary

11 k

V N

etw

ork

1

God

man

ches

ter

Woo

dwal

ton

Brin

gton

RA

F A

lcon

bury

GT2

GT1

Hun

tingd

on G

rid

St Iv

es

Pete

rbor

ough

Pow

erSt

atio

n

CCG

T35

0MW

CCG

T55

MW

P66

P80

P85

P87

P24

P10

NO

P

21

21

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ttle

sey

Funt

ham

s La

ne

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rbor

ough

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h G

T2

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BG

T2B

Ort

on

P28

21

3 4

1

1

3

1

Pete

rbor

ough

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ral

132/

33 k

V2

x 60

MVA

1 2 3

1

12 1

1 2

1

Sou

ther

y

1

1 2

2 1

12

P49

26.6

km

(Pet

erbo

roug

h Ce

ntra

l - M

arch

Grid

)

EM

L W

(S

)

5MW

G

Mar

ch P

rimar

y 11

kV N

etw

ork

9MW

Wis

sing

BSC

G

ener

ator

2.5

2.5

21

2

Max

dem

and

MW

Sum

mer

14.

5W

inte

r 20.

5

0.5

2.5

0.5

216

Wis

sing

BS

C

Swaf

fham

Tee

Wat

ton

Nor

thw

old

Dow

nham

Mar

ket

Wal

tingt

on

Out

wel

lM

oors

King

s Ly

nn G

rid

Wig

genh

all

King

s Ly

nnPr

w S

tn

Stric

tfas

tLa

ne

GT2

Wal

soak

enG

ridG

T1

Wis

bech

Railw

ay

No.

216

MW

No.

116

MW

P19

9.5

km(W

also

ken

- Lev

erin

gton

T2)

Leve

ringt

on

Guy

hirn


1

23

Wal

pole

GSP

Pete

rbor

ough

East

Pete

rbor

ough

Sout

h G

T1 te

eBR

Ne

NE

Pete

rbor

ough

P w

r S tb

tee

Pete

rbor

ough

Nor

th G

T2

Pete

rbor

ough

Cent

ral

33/1

1 kV

EML

W (S

)73

(61)

MVA

Farc

et

12


Ext.

12M

W

16M

W

No.

110

MW

No.

214

MW

Bury

1 2

No.

27.

2MW

No.

12M

W


Upw

ell

Lake

s En

d1

Litt

lepo

rt12

Mar

ch G

rid13

2/33

kV

2 x

45 M

VA

EML

W (S

)59

(43)

MVA

GT1

GT2

12

1020

Mar

ch11

kV



18.3

km

(Mar

ch G

rid -

Funt

ham

s La

ne T

1)

12

Chat

teris

11 k

V

Chat

teris

Prim

ary

11 k

V N

etw

ork

1

God

man

ches

ter

Woo

dwal

ton

Brin

gton

RA

F A

lcon

bury

GT2

GT1

Hun

tingd

on G

rid

St Iv

es

Pete

rbor

ough

Pow

erSt

atio

n

CCG

T35

0MW

CCG

T55

MW

P66

P80

P85

P87

P24

P10

NO

P

21

21

Whi

ttle

sey

Funt

ham

s La

ne

Pete

rbor

ough

Sout

h G

T2

GT1

BG

T2B

Simplified FPP project single line diagram


| 61

Appendix 2

Kings Lynn Grid Tee Waltington

Outwell Moors

Downham Market

Northwold

Swaffham

Watton LINE 1

LIN

E 2

Southery

Littleport

Wissington British Sugar 33kV Switching Station

TAPCON 260 monitored

QB 5-panel Switchboard (QB Switching Station)

A B D

C

3 2 1

1

2

3

8.275km 8.154km

11.07km

5.36

km

6.31km

NC

E

Wissington British Sugar CHP

Key

Existing 33kV

Future 33kV

Existing 11kV

Quad-Booster related network re-configuration

Circuit Breaker closed

Circuit Breaker open

A

B

C

D

E

NC Disconnector (normally closed)

Quad-Booster

On Load Tap Changer

Generator

Downham/Northwold Circuit Breaker

Quad-Booster Downham/ Northwold Side Circuit Breaker

Quad-Booster By-Pass Circuit Breaker (normally open)

Quad-Booster Wissington British Sugar Side Circuit Breaker

Quad-Booster Circuit Breaker at Wissington British Sugar Switching Station

Simplified Wissington 33kV single line diagram


62 |

Appendix 3

33kV

March Grid

To Lakes EndLittleport/ WissingtonTo March West

132kV

2MW 2.5MW 1MW 2MW 0.5MW 2.5MW

5MW11kV

March

1 2

March Primary 11kV Network

Max Demand MWSummer 14.5Winter 20.5

10MW 20MW

10MW

10MW

12

To Whittlesey, Funtham’s Lane

Max Demand MWSummer 11.3Winter 17.4

Chatteris Primary 11kV Network

2MW 0.5MW

11kVChatteris

4.75MW 6MW

GT245MVA

GT145MVA

Existing 132kV

Existing 33kV

Planned 33kV

Existing 11kV

Planned 11kV

Connected Generator

Planned Generator

11kV Load

Reverse Power Flows

33kV Circuit Breaker Closed

11kV Circuit Breaker Closed

Normally Open Point (planned)

132/33kV Transformer

33/11kV Transformer

Key

2.5MW

Reverse Power FlowLimit = 34 MVA per Grid Transformer

Single line diagram for AVC installation


| 63

Appendix 4

Peterborough Central

Farcet

Glassmoor Windfarm

Red Tile 1 Windfarm

Bury Primary(Huntingdon Grid)

504A 504A

671A

671A

March

Funtham’s Lane

Chatteris

Whittlesey

476A 476A

575A

651A

575A

351A

575A

575A

476A 476A

11kV

33kV underground

33kV overhead

33kV underground (new)

Normal open point

Key

Stage 2 - Split ‘Fleet Drove’ tee point and connect Funtham’s Lane circuits direct to Peterborough Central

Single line diagram for RMUs installation at Whittlesey


64 |

Appendix 5Table of evidence

3 P.0142.Flexible Plug and Play Integration Tests specification

4.2.2.3 P.0338.Active Network Management Client Certification

4.2.2.3 P.0339.sgs Connect Certification

4.2.2.3 P.0340.GE Remote Terminal Unit T5500 Certification

4.2.2.3 P.0341.Kalkitech SYNC2000 Certification (Communication interface for the SuperTAPP n+)

4.2.2.3 P.0342.MR TAPCOM260 Certification (QBCS)

4.2.2.3 P.0343.Alstom P341 Certification (dynamic line rating)

4.5.3 P.0334.Dynamic Line Rating 1a Farcet Commissioning Report

4.5.3 P.0335.Dynamic Line Rating 1b Farcet Commissioning Report

4.5.3 P.0336.Dynamic Line Rating 2 Funthams Lane Commissioning Report

4.5.3 P.0337.Dynamic Line Rating 4 March Grid Commissioning Report

4.6.3 P.0318.Active Voltage Control March Grid Commissioning Report

4.6.3 P.0319. Active Voltage Control March Primary Commissioning Report

4.7.2.3 P.0320.Remote Terminal Unit Wissington Commissioning Report

4.7.2.3 P.0321.Remote Terminal Unit March Primary Commissioning Report

4.7.2.3 P.0322.Remote Terminal Unit March Grid Commissioning Report

4.7.2.3 P.0323.Remote Terminal Unit Bury Commissioning Report

4.7.2.3 P.0324.Remote Terminal Unit Peterborough Central Commissioning Report

4.7.2.3 P.0325.Remote Terminal Unit Whittlesey Commissioning Report

4.7.2.3 P.0326.Remote Terminal Unit Chatteris Commissioning Report

4.7.2.3 P.0327.Remote Terminal Unit Littleport Commissioning Report

4.7.2.3 P.0328.Remote Terminal Unit Northwold Commissioning Report

4.7.2.3 P.0329.Remote Terminal Unit Southery Commissioning Report

4.7.2.3 P.0330.Remote Terminal Unit Farcet Commissioning Report

4.7.2.3 P.0331.Remote Terminal Unit Funthams Lane Commissioning Report

4.8.3 P.0332.Novel Protection Relay March Grid Commissioning Report

4.8.3 P.0333.Novel Protection Relay Peterborough Central Commissioning Report

5.2.3 P.0130.Active Network Management Acceptance Test Specification and Results

ReportSection Evidence


| 65

Appendix 6Additional project documentation available to GB DNOs

P.0098.Performance Spec for Enhanced AVC Scheme.

P.0130.Active Network Management Acceptance Test Specification and Results

P.0142.Flexible Plug and Play Integration Tests Specification

P.0154.Flexible Plug and Play Functional and Non-Functional Requirements Specification V1.0

P.0202.High Level Test Approach v1.0

P.0262.Dymanic Line Rating Functional Design Specification

P.0263.Novel Protection Relay Design Specification

P.0264.Quadrature-booster Control System, Production Specification

ReportName

UK Power Networks Holdings LimitedRegistered office: Newington House 237 Southwark Bridge Road London SE1 6NPRegistered in England and WalesRegistered number: 7290590

[email protected]

Documents

| 1 Flexible Plug and Play - UK Power Networks