ACTIVE RESPONSE STORYBOARD - UK Power Networks€¦ · This storyboard is an up-to-date summary of the Active Response project. It is a “living document” that is updated as the

1

104/12/2019 1

ACTIVE RESPONSE STORYBOARD

2

Note to readers

This storyboard is an up-to-date summary of the Active Response project. It is a “living document” that is updated as the project

progresses.

There are sections of the storyboard that have not yet been populated because that aspect of the project has not yet been done or developed. These sections are indicated with orange pages.

3

Introduction

Use Cases

Trials

Project Methods

Operational Requirements

Analysis Algorithms

Other information

Main Menu

ACTIVE

RESPONSE

User Guide

IT/OT Solution

Hardware

4

Active Response Storyboard: User Guide

This storyboard is designed to be used in the following way:

• The user selects the section or subsection that they wish to view from the menu

• At any point the user can navigate to the start of a section or to the main menu (using the links in the top right corner)

• At the end of the section, the user is directed back to the main menu or the section menu

Main Menu

Underlined Text

Main Menu

[Questions]

WORK IN PROGRESS

Navigation Link

Link to another

source of information

Outstanding

Questions

The slide is not

considered complete

5

Version

no.

Date

updated

Details

4.1

4 2 Jul 2019 Updates to slides to reflect current status

3.1 5 Mar 2019 Updates to slides to reflect current status

3 26 Feb 2019 Updated to include Use Cases v2.0 and content from Deliverable 2

2 25 Oct 2018 Major revisions to formatting, layout and content

1 30 Aug 2018 Quarterly update

0 29 Jun 2018 First version based on Full Submission and initial design activities

Active Response Storyboard: Version information Main Menu

6

The diagrams within the Active Response Storyboard use a number of symbols. Many of these are defined within the diagrams, but below is a quick reference guide to the symbols.

Active Response Storyboard: Key

Secondary substations(Colour coding depends on context)

Cable or Overhead Line

Fuse

Circuit Breaker

Open Point

Link Box

Load

Communications Link

Main Menu

Transformer

2-Terminal Soft Open Point


Soft Power Bridge

7

Term Definition

FAT Factory Acceptance Test

FEP Front End Processor

FP Feeder Pillar

FPI Fault Passage Indicators

GPRS General Packet Radio Service

GPS Global Positioning System

HH Half Hourly

HV High Voltage

HVAC High Voltage Alternating Current

HVDC High Voltage Direct Current

IED Intelligent Electronic Device

IRTU Independent Remote Terminal Unit

IT Information Technology

IT/OT Information Technology and Operational Technology

LB Link Box

LCT Low Carbon Technology

LPN London Power Network

LV Low Voltage

Term Definition

ACB Air Circuit Breaker

ADMS Advanced Distribution Management System

ADSL Asymmetric Digital Subscriber Line

ANM Active Network Management

APRS Automated Power Restoration System

BAU Business As Usual

CADD Conceptual Architecture Design Document

CB Circuit Breaker

CE Control Engineer

CI Customer Interruption

CML Customer Minutes Lost

DC Direct Current

DEFPI Directional Earth Fault Passage Indicators

DG Distributed Generation

DNO Distribution Network Operator

DNV Distribution Network Visibility

EPN Eastern Power Network

Glossary of Terms (1) Main Menu

8

Term Definition

QoS Quality of Supply

RMU Ring Main Unit

RT Real Time

RTU Remote Terminal Unit

S/S Substation

S/W Software

SCADA Supervisory Control and Data Acquisition

SCT Sequence Component Transform

SGAM Smart Grid Architecture Model

SOP Soft Open Point

SPB Soft Power Bridge

SPN South Eastern Power Network

SST Solid State Transformer

TF Transformer

THD Total Harmonic Distortion

XLPE Cross Linked Polyethylene

Term Definition

MDI Maximum Demand Indicator

MPAN Meter Point Administration Number

MSS Main Sub Station

MV Medium Voltage

NAREC National Renewable Energy Centre

NHH Non Half Hourly

NIC Network Innovation Competition

NOP Normally Open Point

NRA Normal Running Arrangements

OT Operation Technology

PE Power Electronics

PED Power Electronic Device

PF Power Factor

PILC Paper Insulated Lead Covered

PLCon Programmable Logic Controller

PLC Power Line Communications

Glossary of Terms (2) Main Menu

9

End of Section

Back to Main Menu

10

Introduction

IntroductionProject Plan

Active Response at a glance

Main Menu

WorkstreamsProject Deliverables

11

Active Response at a glance Introduction Main Menu

Hardware Development and

Deployment

• Design, install, commission new SOP and SPB PEDs on HV & LV

Software Development and

Deployment

• Develop software and algorithms to coordinated solution

Project Planning, Trials

and Analysis

• Four trials between 2019 and 2021

• Analyse benefits

Learning & Dissemination

• Document and share learning from trials and research

Workstreams

1. 2. 3. 4.

About

The project will demonstrate two methods to

maximise capacity in four live trials:

• Network Optimise – Optimisation and

automatic reconfiguration of HV & LV networks in

combination, using remote control switches and

Soft Open Points (SOPs).

• Primary Connect – Controlled transfers

between primary substations using a Soft Power

Bridge (SPB) to share loads and optimise

capacity.

Objectives

Partners

Benefits

Funded by Ofgem’s Network

Innovation Competition (NIC).

• Total Budget: £17m

• NIC funded: £13.8m

• UKPN funded: £3m

• Duration: 2018-2021

Benefits will include a cost

effective solution to facility the

connection of LCTs, improved fault

level control, voltage control and

asset protection in the LV network.

• Saves £9 per customer (NPV to

2030)

• Break even 2 years after trial

Scale Financial MVA CO2 (t)

Single

2050

£981 k 11.5 7.02

UKPN

2030

£59.6 m 928 4,284

UKPN

2050

£155.5 m 1,481 8,679

GB

2030

£270.6 m 4,228 19,592

GB

2050

£721.7 m 6,962 40,727

12

Active Response Introduction

Main MenuIntroduction

13

Active Response is designed to manage the uncertainty that is being experienced due to the growth of Low Carbon Technologies (LCTs). The solution will be able to respond quickly to the clustering of LCTs, particularly EVs, allowing more to connect without exceeding thermal and voltage limits.

Increasing demand and connected distributed generation have previously been dealt with though network reinforcement. The network is designed to accommodate the peak demand or peak generation. This may not be a cost effective solution if the peak only occurs for a few hours of the day or only for a few months of the year caused by seasonal variation.

LCT growth forecasts predict a large uptake which would require a large amount of reinforcement and significant future costs to customers and additional network disruption.

Active Response aims to add to UK Power Networks’ smart solution toolbox to facilitate the connection of LCTs to its distribution networks.

Active Response Introduction Introduction Main Menu

14

Financial benefits

• Initial calculations suggest over £700m in direct financial benefits up to 2050 across GB

Capacity benefits

• Initial calculations suggest over 6,000MVA capacity released up to 2050 across GB

Emissions benefits

• About 40,000 tCO2e saved directly by the methods up to 2050 across GB, as well as ‘indirect’ savings through supporting the connection of low carbon technologies (LCTs) and the considerable carbon benefits of a green future society.

Financial, Capacity & Emissions Benefits Main MenuIntroduction

The business case modelling has focussed on the deferment of reinforcement of the network to

quantify financial, capacity, and emissions benefits associated with deferral or mitigation of network

reinforcement:

15

Faster and more cost-effective distributed generation connection offers

• Frequently these require primary reinforcement, which can take several years to implement due to legal and outage constraints.

• Active Response solutions are quicker to implement, due to their small physical size, and release capacity from existing assets.

• Active Response solutions could also be cost effective as temporary solutions to enable a connection while primary reinforcement is being carried out.

Increased network flexibility

• The provision of quickly deployable and flexible methods, and the increased network visibility and control associated with the methods, enables future uncertainty and the impacts of LCTs to be managed more effectively.

• For example, further capacity could be released by the Network Optimise method if it is used to form larger HV feeder groups while keeping the operation and emergency switching requirements to a manageable level.

Reduction in customer disruptions

• Reduced disruption and logistical benefits associated with network reinforcement projects.

• Potential reduction in LV fuse operations associated with overload (enabled by Network Optimise).

Network control benefits

• Power electronics will provide the ability to manage network voltage and power flows, which can offer customers improved quality of supply.

Other Benefits Main MenuIntroduction

16

This will be achieved using two methods:

Project aims will be achieved through 2 Methods Main MenuIntroduction

Network Optimise

Optimisation and automatic reconfiguration of HV and LV

networks in combination using remote controlled switches

and soft open points

Primary Connect

Controlled transfers between primary substations using a soft power bridge to share load and optimise capacity

The aim of Active Response is to demonstrate advanced automation to optimise

network arrangements in LV and HV networks as well as novel power electronics

connecting adjacent networks to maximise capacity.

17

The project is comprised of multiple solutions Main MenuIntroduction

The overall Active Response solution combines Network Optimise with Primary Connect

Network Optimise is comprised of 3 solutions, which can be implemented in isolation or in combination

Network Optimise

Primary Connect

Active LVSecondary Connect

Using Soft Open Points to manage power flows

Remote switching of LV network (without power electronic devices)

Active HV

Remote switching of HV network to move open points

(without power electronic devices)

Active Response Methods

18

• Provides additional capacity by automatically configuring the network:

• Optimising the open points around the HV network.

• Reconfiguring the LV network to optimise and reflect any changes in network boundaries.

• Using power electronics to manage LV power flows.

• Optimisation techniques will be demonstrated based on modelling of the LV and HV networks to determine how automatic reconfiguration can increase the utilisation of assets to increase the amount of LCTs that can be connected.

• ANM will enable active reconfiguration and network meshing to determine the best arrangement of the LV and HV network.

• ANM will apply the optimal network configuration, monitor performance and periodically reassess conditions and requirements

Method 1: Network Optimise

Optimisation and Automatic Reconfiguration

of HV & LV networks in combination, using

remote control switches and SOPs


More on Methods

19

• Allows dynamic support between adjacent Primary Substations to meet load conditions.

• Interconnections between Primary Substations offer benefits by enabling high demands at one substation to be partially met by the other substation.

• Periods of high demand at Substation 1 are supported by importing power from Substation 2 through the Soft Power Bridge and vice versa.

• With increasing LCT penetration it is anticipated that load profiles at primary substations will become highly dynamic, with adjacent substations seeing peak demands at different times of day, depending on the type of customers they supply.

• Sharing of loads and generation between Primaries can be used to reduce peak demands, thereby deferring the need to reinforce.

Method 2: Primary Connect

Controlled transfers between

primary substations using a

SPB to share loads and optimise

capacity


More on Method 2

20

Active Response is the combination of the 2 methodsActive Response = Primary Connect + Network Optimise

Automation, optimisation and power electronics to enable load sharing at HV and LV


Primary Connect

enabled by SPB

Network Optimise

comprising 3

solutions

21

Active Response methods will add to the network planning toolbox

The network planning decision-making process is shown below with the toolbox of

potential solutions ordered from lowest to highest cost


Identify network

constraintMonitor network

& build / update

network model

If the issue can be fixed via

DSR or other smart measureDSR or other

If periodic network

reconfiguration can solve

the constraints

Network

Optimise

Primary

Connect

If support from another

primary substation is

required

Traditional

Reinforcement

If no lower cost solution is

possible

Asses issues

and identify

most cost

effective

solution

Operate

and

monitor

solution

TOOLBOX OF

POTENTIAL SOLUTIONS

Developed through Active Response

Feedback loop – where the characteristics of the problem change

Active HV

Secondary connect

Active LV

22

Four trials are planned in UK Power Networks’ licence areas:

The Methods will be demonstrated in 4 Trials

Trial Name Description

1 Active HV HV Network optimisation only

2 Network Optimise HV and LV Network Optimisation, including LV

switches and SOPs

3 Primary Connect Direct Connection between Primary

substations using an SPB

4 Active Response Network Optimise and Primary Connect in

combination


23

Project Structure Main MenuIntroduction

UKPN Internal

UKPN Contractor

Partner

Project Sponsor

Senior Responsible Officer

Project Lead

Project Steering Group

Project Management Office

Stakeholder engagement

Legal SupportFinancial Support

Procurement Support

Regulation support

Technical Design Authority

DNO Peer Review (SPEN)

Engineering Standards

Distribution Planning

Infrastructure Planning

Safety

IS Architecture

Control Systems & Automation

Project Office Manager

Hardware Development and Deployment

Turbo Power Systems (Lead)

Ricardo Energy & Environment

Hardware Suppliers

WS1

Software Development and Deployment

WS2

UKPN (Lead)

CGI

Project Planning, Trials and Analysis

Ricardo Energy & Environment (Lead)

WS3

Learning and Dissemination

WS4

Ricardo Energy & Environment

UKPN

Academic Review (TBC)

Independent Review (TBC)

UKPN

SPEN

Ricardo Energy & Environment (Lead)

Project SupportRicardo Energy &

Environment

ANM software supplier

24

SP Energy Networks are a DNO partner who will act as a Technical Design Authority and support knowledge dissemination activities including co-authoring a document outlining the use of Power Electronics in Distribution Networks.

• They bring the expertise of operating and managing a distribution network in a different geographical area.

• They will be able to advise on the applicability of the solution in a different distribution network.

CGI owns the planning tool DPlan used by UKPN. CGI’s input to Active Response includes:

• DPlan specific aspects, including enhancing DPlan to model SOPs, and visualization and chronological power flow analysis of radial and meshed for the before and after states of smart device deployment and operation;

• Project IT and Data-set Creation and Management; and

• Contribution to Knowledge Transfer.

Turbo Power Systems are the lead manufacture and have expertise in:

• Power electronic design

• Manufacturing of power electronics

Ricardo are lead consultants supporting Active Response and have expertise in:

• Network design

• Power electronics

• Planning and analysis expertise

Project Partners

Workstreams

1, 2, 3 & 4

Workstream 2


Workstream 1

Workstream 2

25

Workstreams


26

Workstream Learning Objectives

1 Hardware Development and

Deployment

Trail and review of SOP / SPB hardware designs so that the most

appropriate architectures can be identified and developed for adoption.

Consideration of the Methods impact on asset life, network operations,

safety requirements and risk management.

2 Software Development and

Deployment

Practical experience of hierarchical control systems.

Review and demonstration of network optimisation algorithms and state-

estimation techniques.

Knowledge if effective data analytics systems, in which large volumes of

data are processed into useful, actionable information.

3 Project Planning, Trials and

Analysis

Research into LCT growth and clustering assumptions.

A review of the Active Response project business case and the use

cases.

An initial draft, in conjunction with Scottish Power Energy Networks, of a

planning guide on the use of power electronic solutions in Distribution

Networks.

4 Learning & Dissemination Effective dissemination of the learning derived over the course of the

project.

Workstreams Main MenuIntroduction

27

Project Deliverables


28

Deliverable Evidence Status

1 High Level Design Specification of Advanced

Automation Solution

Report outlining the requirements and options for

the Active Response software solution

Submitted

2 Trial Site Selection Criteria and Process

Outcome

Description of possible site selection criteria,

derivation of the selected methodology and details

of the networks selected for the 4 project trials

Submitted

3 Learning from Hardware Factory Tests Details of the key learning from the hardware

specification, design and testing process

Due 2020

4 Learning from Commissioning and Operation

of Active Response Software Solution tools

Report outlining the key learning from the initial

off-line trials of the project software tools

Due 2020

Project Deliverables (1) Main MenuIntroduction

The following ten Project Deliverables will be generated through the course of Active Response.

They have been designed to demonstrate clear progress towards the project objectives and

disseminate valuable learning.

Note: Follow the links to submitted Deliverables

https://innovation.ukpowernetworks.co.uk/wp-content/uploads/2019/05/Active-Response-Project-Deliverable-1-Report.pdf


29

Deliverable Evidence Status

5 Initial Learning from the Installation and

Commissioning of Active Response

Hardware

Report outlining the key learning from the initial

installation and commissioning of the project

hardware

Due 2020

6 Project technology handover, rollout and

adoption into business-as-usual plan

Implementation plan for the adoption of the project

solutions into business-as-usual

Due 2021

7 Review of the Active Response methods

applicability in Scottish Power Energy

Network licence areas

A report by Scottish Power Energy Networks

detailing the number implementations in their license

areas that the project methods provide benefits

Due 2021

8 Presentation of findings from the project

trials

Analysis and findings from the 4 project trials,

including key learning and recommendations

Due 2021

9 Review of solution applications and

project business case

Comparison of the project technology following the

trials against that envisaged at inception, and review

of applications and benefits

Due 2021

Close-Down Report Due 2021

Project Deliverables (2) Main MenuIntroduction

30

Project Plan


31

Project plan

Development of Advanced Automation Solution (in stages)

Close-DownReport

Project Close-down

PED installation, commissioning & operation

(Trials 2 & 3)

PED installation, commissioning & operation (Trial 4)

2019 20202018 2021

Specification, Design and Development of Power Electronic Devices

Specification, Procurement, Development and Manufacture of LV circuit breakers and switches

PED Component, Functional & Qualification Testing

Detailed Use Case development & conceptual design

Trial Design & Site Selection

Trials 2 & 3

Publicising deliverables and project findings

WS1: Hardware Development and

Deployment

WS3: Project Planning, Trials

and Analysis

WS4: Learning and

Dissemination

Trial 1

WS2: Software Development

and Deployment

Internal & External Stakeholder Engagement

Specification, Design and Development of IT/OT solution architecture

Data migration, build and testing

Trial 4

Use Case & Business Case Review

Business-as-Usual Handover

Trial Analysis and Review

Ongoing Development &

Support

Procurement of Active Network Management software supplier

Deliverable 1(Submitted)

Deliverable 2(Submitted)

Deliverable 4

Deliverable 5

Deliverable 6

Deliverable 8

Deliverable 9

Deliverable 3

Deliverable 7

Trial Detailed Design

Planning for and implementing installation works


32

Please select a link to continue and exit this section

End of Introduction Section

Back to Main Menu

Back to Introduction Menu

33

Hardware

Soft Open Points

Conventional LV Equipment

Main Menu

Soft Power Bridge

Hardware Menu

Conventional HV Equipment

Overview

34

Hardware Overview

Main MenuHardware

35

Hardware for Active Response

Method 1:

Network Optimise

• Second Generation 2-Terminal Soft Open Points

• Second Generation 3-Terminal Soft Open Points

• Ring Main Units

• LV Circuit Breakers

• Link box switches

Method 2:

Primary Connect

• Soft Power Bridge

Model of second generation 3-Terminal Soft Open Point

Model of second generation 2-Terminal Soft Open Point

36

Soft Open Points

Main MenuHardware

37


Device Operation

• Connected at across an LV link box.

• Need to ensure that all loads

connected to the network always

have an electrical connection to a

transformer.

• The device transfers power across

two feeders to equalise loading

across two networks or to equalise

the voltage across the NOP.

• Q can be controlled independently

per port

• Second generation devices will be

smaller, lighter and quieter.

Device Inputs

• P, Q set points

Device Limitations

• Current limited device

P, QP, Q

Ploss

LB

38


P, Q

P, QP, Q

Ploss

Device Operation

• Typically installed in an LV substation.

• The device transfers power across

three feeders to equalise loading across

three networks or to equalise the

voltage across the NOP.

• Q can be controlled independently per

port.

• Second generation devices will be

smaller, lighter and quieter.

Device Inputs

• P, Q set points

Device Limitations

• Current limited device

39

Soft Power Bridge

Main MenuHardware

40

Device Operation

• A power electronic device which controls real power and reactive power.

• Transfer of real and reactive power.

• Connects between two HV feeders.

Soft Power Bridge Overview

Device Limitations

• The device may only block a specified voltage.

– If the voltage at the terminals is greater than the device rating, the

device must disconnect.

• The device is current limited and has no over current capability unless

the semi-conductor devices are over rated.

• Device can only transfer within a specified voltage difference and

phase angle difference.

Device Inputs

• Real power and reactive power set-points.

• Terminal voltage.

• Other inputs are possible via a

communications network.

Primary Substation 1

HV Busbars


HV Busbars

Option 1: Interconnection

between substation busbars


between HV networks

Normally Open Point

Secondary

Substation RMU

Soft Power Bridge

RMU for Soft Power

Bridge connection

41

Soft Power Bridge Capacity Release Example

Total capacity: 20 MW

Loading: 18 MW

Primary Utilisation: 90 %

Total capacity: 30 MW

Loading: 18 MW

Primary Utilisation: 60 %

SPB should transfer

power from Primary 1

to Primary 2 to reduce

substation loading

Information required:

• Primary utilisation

• Load measurement (real time data)

• Firm capacity (asset database)

• HV feeder loading

• SPB voltage

Asset Guarding:

• Voltage

• SPB should not cause the HV voltage to

rise outside of limits

• SPB has a local voltage measurement

• HV feeder loading

• SPB should not overload the HV feeder

• HV feeder load measurement required

Algorithms:

• Optimisation for losses: only transfer power

required to minimise losses

• Threshold: only transfer power required to

maintain Primary loading to below a threshold

(for example, transfer 2 MW to ensure Primary A

is below maximum of 80 % loading)

• Equalisation: transfer power to equalise

Primary loading. System utilisation is 72 %, 3.6

MW of transfer is required.


HV Busbars


HV Busbars

42

Soft Power Bridge – Arrangement

Model showing general arrangement of the soft power bridge

Model showing rear view of the soft power bridge

43

Soft Power Bridge – Overall Diagram

Master Control

Control Cubicle

Fibre Optic

Control

Lines

Fibre Optic

Control

Lines

Fibre Optic

Control

Lines

Input Power

Transformer

Input Enclosure With Triplex Cable

Termination Box

CT

Control

And Supply

Feedback


Termination Box

CT

Control

And Supply

Feedback

HV Switch

HV Switch

HV Switch

External

I/O

Lines

SUB-A SUB-B

External

RMU

External

RMU

Mo

du

le C

on

tro

l C

ard

PWM

Filter

A CD C

A CD C

PWM

Filter

EMC

Filter

EMC

Filter

PED

Control

Interface

PED

Control

Interface

PED

Control

Interface

External

Ancillary

PowerRTU

HMI

(optional

extra)

HV Switch Control

Interface

Input

PED

(3 Ph)

Output

PED

(1 Ph)

PED

Mo

du

le C

on

tro

l C

ard

PWM

Filter

A CD C

A CD C

PWM

Filter

EMC

Filter

EMC

Filter

Mo

du

le C

on

tro

l C

ard

PWM

Filter

A CD C

A CD C

PWM

Filter

EMC

Filter

EMC

Filter

In/Out CubicleIn/Out Cubicle

MV SOP

Product

Breakdown

SPB

Water

cooling

Fibre Optic

Control

Lines

Document: 304-01-024

44

Soft Power Bridge – PED Modules

Front view of the PED module Rear view of the PED module

45

Master Control

Control Cubicle

Fibre Optic

Control

Lines

Fibre Optic

Control

Lines

Fibre Optic

Control

Lines

Input Power

Transformer


Termination Box

CT

Control

And Supply

Feedback


Termination Box

CT

Control

And Supply

Feedback

HV Switch

HV Switch

HV Switch

External

I/O

Lines

SUB-A SUB-B

External

RMU

External

RMU

Mo

du

le C

on

tro

l C

ard

PWM

Filter

A CD C

A CD C

PWM

Filter

EMC

Filter

EMC

Filter

PED

Control

Interface

PED

Control

Interface

PED

Control

Interface

External

Ancillary

PowerRTU

HMI

(optional

extra)

HV Switch Control

Interface

Input

PED

(3 Ph)

Output

PED

(1 Ph)

PED

Mo

du

le C

on

tro

l C

ard

PWM

FilterA C

D C

A CD C

PWM

Filter

EMC

Filter

EMC

Filter

Mo

du

le C

on

tro

l C

ard

PWM

Filter

A CD C

A CD C

PWM

Filter

EMC

Filter

EMC

Filter

In/Out CubicleIn/Out Cubicle

MV SOP

Product

Breakdown

SPB

Water

cooling

Fibre Optic

Control

Lines

Document: 304-01-024

Soft Power Bridge – PED Modules

VT

CT

1100V VT

CT

CT

CT

VT VT VT

Interface

Card

Supply

Liquid Cooled Heat Sink

Liquid Coolant

Dual GD

Dual GD

Dual GD

Dual GD

Dual GD

Dual GD

Dual GD Dual GD

Dual GD Dual GD

OUTPUT PED INPUT PED

Dual GD Dual GD

Dual GDDual GD

SiC MOSFET Driver Cards Interface

Current and Voltage Transducer InterfaceLocal Control

PED Module (x3)

46

Conventional LV Equipment

Main MenuHardware

47

LV Equipment

LV Circuit Breakers

Device Operation

• Installed on the LV busbar in the

secondary substation.

• The device is able to open and close the

circuit onto the bus bar.

• In the event of a fault, the device will

disconnect the feeder from the busbar.

Device Inputs

• Open

• Close

Device Limitations

• The number of switching operations is

tested to 1,000.

• Reason for constraint is unclear.

Link box switches

Device Operation

• Installed in the LV link box

• The device is able to open and close the

four quadrants of the link box

• The device is able to break fault current

up to 6 kA and fuse operation up to 46

kA.

Device Inputs

• Open

• Close

Device Limitations

• The number of switching operations is

tested to 1,000.

• Reason for constraint is unclear.

• Device losses causing overheating and

malfunction

The LV equipment is used to remotely reconfigure the LV network and enable automation

48

Conventional HV Equipment

Main MenuHardware

49

Device Inputs

• 11 kV feeder 1 switch

• Open

• Closed

• 11 kV feeder 2 switch

• Open

• Closed

Device Limitations

• The number of switching operations is tested to between 2,000 and 5,000

• It is unknown if the device could operate 10,000 or more switching operating under normal loading conditions

HV Equipment

Transformer mounted air circuit

breaker & Ring Main Unit

Device Operation

• A ring main unit (RMU) normally has two 11 kV ring circuit connections, these may have capacitor bushings for detection of HV volts.

• There is a switch on both 11 kV ring circuits. one or both of these may be remotely operable, the LH switch may have CTs for ring current measurement

• RMUs are connected in series along the 11 kV feeder circuit

• Normally Open Points (NOP) are created in the 11 kV network by opening one of the ring circuit switches

• To move the NOP in an 11 kV network, the open ring switch needs to be closed and the other opened (phase synchronisation may need to be checked if across HV boundary)

• If both ring switches have remotely controlled actuators then a “Flip Flop” mode can be selected that enables an HV normal open point at an RMU to be autonomously

reselected to the other side of the RMU if HV supply to the RMU is lost and there is supply available via the other ring circuit

500:1

HV Capacitor

bushing

50


End of Hardware Section

Back to Main Menu

Back to Hardware Menu

51

Methods and solutionsMain Menu Overview

Primary Connect

Methods &

Solutions

Active LV

Active HV

Secondary Connect

Network Optimise

Combined

52

Overview of Methods & Solutions

Network Optimise

Primary Connect

Active LVSecondary Connect

Using Soft Open Points to manage power flows

Remote switching of LV network (without PEDs)

Active HV

Remote switching of HV network to move open points (without

PEDs)

Active Response Methods

Network Optimise is comprised of 3 solutions

Two Methods:

1) Network Optimise (comprising of one HV and two LV solutions)

2) Primary Connect

Methods & Solutions Main Menu

53

Network Optimise – Active HV


54

Active HV Concept Overview

Primary Substation

Secondary Substation RMU

HV Busbars

Normally open point

Feeder AFeeder B

Feeder C

Fe

ed

er

Lo

ad

ing

(M

W)

Time

Feeder A capacity limit

Additional headroom

created on Feeder A

Open point moved

Feeder A load

Feeder C loadA6 C6

Move HV normally

open point to transfer

load from feeder A to

feeder C

55

• 3 feeder 11 kV ring shown as example.

• Normally run split at 3 NOPs.

• NOPs selected to provide reasonable even loading of the three feeders in normal circumstances (certainly no overloads are seen).

• Loads follow the same profile and are predictable, network is sized to meet the peak demand and provide redundancy.

• If one of the feeders were to have a fault, the network could be reconfigured to supply the demand.

• The difference substations may have different profiles

Network Optimise – Active HV Example (1)

11kV MSS Busbars

0

200

400

600

800

1000

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Lo

ad

(kV

A)

Time

Commercial Load Profile

0

100

200

300

400

500

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00L

oa

d (

kV

A)

Time

Residential Load Profile

TF & RMU

NOP

Heavily

loaded

Lightly

loaded

Key

56

• Three substations become heavily loaded during the day and cause one of the three HV feeders to become overloaded.

• Network Optimise detects the feeder overload and runs an optimisation algorithm to determine the optimal positions of the normally open points to balance the loading across the HV network.


11kV MSS Busbars

0

200

400

600

800

1000

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Lo

ad

(kV

A)

Time


0

100

200

300

400

500

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00L

oa

d (

kV

A)

Time


13:00

TF & RMU

NOP

Heavily

loaded

Lightly

loaded

Key

57

• The open points are moved and the network reconfigured to balancing the loading across the three feeders.

• If the LV network is meshed, it may require reconfiguration before the HV network can be reconfigured.

• ALTERNATIVE: Reconfiguring the LV network may also solve the HV network constraints and have a lower operational cost than HV reconfiguration.


11kV MSS Busbars

0

200

400

600

800

1000

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Lo

ad

(kV

A)

Time


0

100

200

300

400

500

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00L

oa

d (

kV

A)

Time


13:00

TF & RMU

NOP

Heavily

loaded

Lightly

loaded

Key

58

• Later in the evening, the substations with the residential profiles start to have a high capacity. The HV feeder supporting the residential loads has available capacity.

• Network Optimise detects the overload in the adjacent feeder and runs an optimisation algorithm to determine the optimal positions of the normally open points to balance the loading across the HV network.


11kV MSS Busbars

0

200

400

600

800

1000

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Lo

ad

(kV

A)

Time


0

100

200

300

400

500

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00L

oa

d (

kV

A)

Time


19:00

TF & RMU

NOP

Heavily

loaded

Lightly

loaded

Key

59

• The open points are moved and the network reconfigured to balancing the loading across the three feeders.


11kV MSS Busbars

0

200

400

600

800

1000

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Lo

ad

(kV

A)

Time


0

100

200

300

400

500

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00L

oa

d (

kV

A)

Time


19:00

TF & RMU

NOP

Heavily

loaded

Lightly

loaded

Key

Jump to Trial 1: Active HV

60

Network Optimise – Active LV


61

Active LV Concept Overview

Primary Substation


HV Busbars

Normally open point

LV Loads

Feeder AFeeder B

Feeder C

A6 C6

LV Loads

Soft open point

Link box switch

between LV networks

closed to share load

between LV feeders

C5 and C6

C5

Link box switch

Se

co

nd

ary

Su

bs

tati

on

Lo

ad

ing

(M

W)

Time

C6 capacity limit

Additional headroom

created on C6

Link box switch

closed

C6 load

C5 load

Link box switch

opened

62

Network Optimise – Active LV Example (1)

LV LoadsLV Loads

LV Busbars

LV Loads

• An example LV network is shown with link boxes

to allow for load to be moved from one substation

to another substation.

• Normally the LV networks are run radially.

Examples of meshed LV networks exist in London

and Liverpool (Manweb).

• Reconfiguration requires a person to visit site and

manually remove or add links to reconfigure the

network.

• By adding remote controlled circuit breakers

(RCCB) and link box switches (LBSW) into the

network, the LV networks can be reconfigured

depending on the load in the LV network.

Tx A

Tx C

Tx B

Link box

NOP

Lightly

loaded

Key

RCCB

Average

loading

Heavily

loaded

63


LV LoadsLV Loads

LV Busbars

LV Loads

• A cluster of LV appears on the LV feeder shown in

red causing the feeder and substation to become

heavily loaded.

• Active Response uses the RCCBs and LBSWs to

understand the network loading.

• An optimisation algorithm runs to determine the

optimal running arrangement of the LV network.

13:00Tx A

Tx C

Tx B

Link box

NOP

Lightly

loaded

Key

RCCB

Average

loading

Heavily

loaded

64


LV LoadsLV Loads

LV Busbars

LV Loads

• The optimisation algorithm identifies the optimal

running arrangement of the network by moving the

open points to rebalance the LV feeders and

substation loading.

• After the open points have been moved the load

on the heavily loaded feeder and substation is

reduced and shared between the other LV

networks.

13:00Tx A

Tx C

Tx B

Link box

NOP

Lightly

loaded

Key

RCCB

Average

loading

Heavily

loaded

65


LV LoadsLV Loads

LV Busbars

LV Loads

• The EV cluster disappears and moves to a

different location in the LV network.

• This causes a different feeder and substation

to become heavily loaded.

19:00Tx A

Tx C

Tx B

Link box

NOP

Lightly

loaded

Key

RCCB

Average

loading

Heavily

loaded

66


LV LoadsLV Loads

LV Busbars

LV Loads

• Active Response calculates the optimal

configuration of the LV network and

reconfigures by moving the open points in

the network

• The network load is balanced around the LV

network

• The LV network may also need to be

rebalanced to solve any constraints on the

HV feeders.

19:00Tx A

Tx C

Tx B

Link box

NOP

Lightly

loaded

Key

RCCB

Average

loading

Heavily

loaded

67

Network Optimise – Secondary Connect


68

Secondary Connect Concept Overview

Primary Substation

HV Busbars

LV Loads

Feeder AFeeder B

Feeder C

A6 C6

LV Loads

Soft open point used

to manage load

transfer between LV

feeders A6 and C6 (on

different HV feeders)

C5


Normally open point

Soft open point

Link box switch

Se

co

nd

ary

Su

bs

tati

on

Lo

ad

ing

(M

W)

Time

A6 & C6 capacity limit

Additional headroom

created

Load transfer from

C6 to A6 using SOP

C6 load

A6 load

Load transfer from

A6 to C6 using SOP

69

Network Optimise – Secondary Connect Example (1)

LV Loads

LV Loads

• An example LV network is shown with SOPs to

allow for transformer equalisation to share load

across multiple LV networks.

• Each load on the network must always have a

connection to a substation with a transformer

• SOPs can be places across electrical boundaries

and prevent fault current from passing from one

network to another network.

• SOP can be connected to both meshed and radial

networks.

• SOPs can be instructed to manage:

• The voltage at the terminals

• The voltage unbalance

• The voltage harmonics

• Follow a PQ set-point which can be set to

equalise transformer network loadings or

feeder loadings.

Tx C

Tx B

LV Loads

LV Busbars

Tx A

Port BPort A

Port CLink box

NOP

Lightly

loaded

Key

Average

loading

Heavily

loaded

3T SOP

2T SOP

70

Port C

Port A


LV Loads

LV Loads

• A cluster of EVs appears on one of the

feeders causing the substation load to

increase and approach the maximum

loading.

• Active Response has either previously

forecast load or is monitoring the

network to understand the network

power flows.

13:00

Tx C

Tx B

LV Loads

LV Busbars

Tx A

Port B

0%

20%

40%

60%

80%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time

Transformer Equalisation

Transformer A Transformer B Transformer C

Equalised Time Reference

Link box

NOP

Lightly

loaded

Key

Average

loading

Heavily

loaded

3T SOP

2T SOP

71

Port B

Port C

Port A


LV Loads

LV Loads

• The set-point is calculated by Active

Response and communicated to the SOPs

through the SCADA system.

• The SOPs follow the set-point and transfer

power from one port to another port.

• The transfer of power injects power into the

heavily loaded feeder. It is now supplied from

both ends and the load is shared between

the SOP and the substations.

• The overall substation loading is reduced and

the load shared across all substations.

• The SOPs output would change gradually to

optimise the network.

13:00Tx B

Tx C

LV Loads

LV Busbars

Tx A

-300

-200

-100

0

100

200

300

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Tra

nsfe

r (M

VA

)

Time

SOP Operation

Port A Port B Port C Time Reference

Link box

NOP

Lightly

loaded

Key

Average

loading

Heavily

loaded

3T SOP

2T SOP

72


LV LoadsLV Loads

LV Busbars

LV Loads

• The loading in the network changes and

a different feeder becomes heavily

loaded if the SOPs were not connected.

• The set-point of the SOPs is gradually

changing to optimise the network

loading.

19:00Tx A Tx B

Tx C

Port APort B

Port CLink box

NOP

Lightly

loaded

Key

Average

loading

Heavily

loaded

3T SOP

2T SOP

0%

20%

40%

60%

80%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time


Transformer A Transformer B Transformer C

Equalised Time Reference

73


• The addition of the SOPs balance the

network loading.

• The transfer through the SOP changes

to reduce the loading on the feeder

which is most loaded.

19:00

LV LoadsLV Loads

LV Busbars

LV Loads

Tx A Tx B

Tx C

Port APort B

Port C

-300

-200

-100

0

100

200

300

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Tra

nsfe

r (M

VA

)

Time

SOP Operation

Port A Port B Port C Time Reference

Link box

NOP

Lightly

loaded

Key

Average

loading

Heavily

loaded

3T SOP

2T SOP

74

Network Optimise Combined Solution


75

Network Optimise Comprising Active HV, Active LV & Secondary Connect

Primary Substation


HV Busbars

Normally open point

LV Loads

Feeder AFeeder B

Feeder C

LV Loads

A5 A6 C6

LV Loads

Soft open point

SOP1SOP2

LV open point is moved from SOP1 to

SOP2 when the HV boundary is moved to

between A5 and A6

LV Busbars

C5Link box switch

Active HV

Active LV

Secondary

Connect

Jump to Trial 2: Network Optimise

76

Primary Connect


77

Primary Connect Concept Overview


HV Busbars


HV Busbars

Secondary Substation RMU Normally open point


between substation

busbars

Option 2. Interconnection

between HV networks

78

• Primary substations feed the 11 kV network

• Typically the 11 kV network is run radially with interconnects between Primary substations

• Interconnects enable reconfiguration during maintenance or outages

• Active Response aims to use these interconnectors to share capacity between substations where:

• A Primary substation with capacity could support another primary substation experiencing a constraint, or

• Benefits from bidirectional transfers (If transfer is only required in one direction, solution is to move load to rebalance the Primaries)

• The SPB is able to transfer power with more granular control than moving normally open points

Primary Connect Example (1)

Primary A Primary B

HV Network A HV Network B

SPB

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time


Primary A Primary B Equalised

79

• Primary substation A feeds a commercial district and experiences a peak loading at mid day.

• Primary substation B feeds a residential district and experiences a peak loading in the evening.


Primary A Primary B


SPB

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time


Primary A Primary B Equalised Time Reference

13:00

80

• The SPB transfers power from Primary substation B to Primary substation A.

• Load is reduced at Primary substation A and increased at Primary substation B.

• Spare capacity from Primary substation B is used to allow more load to connect to Primary substation A and increase capacity.

• However a study is required to understand if the network would remain P2/6 compliant.


Primary A Primary B


SPB

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time



13:00

81

• Due to the different load profiles, in the evening, substation B becomes heavily loaded and substation A is lightly loaded.


Primary A Primary B


SPB

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time



19:00

82

• The SPB transfers power from Primary substation A to Primary substation B to reduce the peak load.


Primary A Primary B


SPB

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 00:00

Utilis

atio

n (

%)

Time



19:00

Jump to Trial 3: Primary Connect

83

End of Section

Back to Main Menu

84

Trials

Overview of Trials

Trial 1: Active HV

Main Menu

Trial 2: Network OptimiseTrial 3: Primary Connect

Trial 4: Active Response

Trials menu

85

Overview of Trials

Main MenuTrials

86

The aim of the Active Response trials is to demonstrate the optimisation algorithms developed for the

Advanced Automation, the correct operation of the Power Electronics hardware and to develop the

hardware to TRL 8. The trials will demonstrate a range of the possible applications which the solution can

be applied to and show the benefits which are provided both to the network and to customers.

Before the trials start, to ensure they are completed successfully, the following steps will be carried out:

• Detailed specifications, test criteria and designs will be developed, reviewed and approved by the project

partners;

• The trial areas will be selected and design work for the trials carried out. This will ensure that maximum

benefit can be obtained from the trials and all the necessary data is collected;

• The SOP and SPB will be tested at an appropriate facility witnessed by SPEN and UK Power Networks;

and

• Software testing will be carried out on a test environment.

The trials will build in complexity over the course of the project to minimise risk to both customers and the

network.

Aims of Trials Main MenuTrials

87

Trial Description Approx.

Start

Approx.

End

1 Active HV Demonstrate the benefits of automated HV network optimisation

only.

Sep 2019 Mar 2020

2 Network

Optimise

Demonstrate the combined Network Optimise method: Benefits of

automated HV and LV network optimisation in combination, using

soft open points and LV switches.

Jan 2020 Jun 2020

3 Primary

Connect

Demonstrate the ability of the soft power bridge to release

network capacity by managing primary substation peak demands.

Jan 2020 Jun 2020

4 Active

Response

Active Response will demonstrate both project methods in

combination. This will enable the complete solution to be trialled

to prove that the technologies operate in conjunction with each

other to maximise the benefits.

Jan 2021 Jul 2021

Summary of Trials Main MenuTrials

A detailed description of the trial site selection criteria and process outcome can be found in Project Deliverable 2.

Download link - Deliverable 2: Trial Site Selection Criteria and Process Outcome


88

Trial 1:

Active HV

Trial Design

Site SelectionResults

Main MenuTrialsTrial 1: Active HV

89

Trial 1 is focussed on the “Active HV” solution on the 11 kV system only (i.e. not at the LV level) without the use of power electronic devices. This will be achieved by opening and closing 11 kV ring switches to change the locations of normally open

points in the HV network based on instructions from the Advanced Automation and Optimisation System.

Design for Trial 1: Active HV Main MenuTrialsTrial 1

•Radial 11kV network with 3 or 4 source feeders from the same Primary Substation

•Diversity of load profiles on the feeder group so there is scope to share load between feeders

•Some sites/feeders should be heavily loaded during some periods

•LV Networks should be arranged radially

•LPN groups in central London (see map to left) which are interconnected should be excluded because open points provide first HV outage support

•Remote HV switching possible at a fair proportion of sites in the group

•There should be good interconnection to other load groups on the same primary substation, to allow for the simulation of rapid changes in load if required

•There should not be any large customer connections (e.g. hospitals or large single users) or IDNOs with loads sensitive to network switching or where supplies are critical

•Requirements

•Network Configuration

•Feeder/site loadings for 12 months

•Equipment types

Data required for Selection process

•HV NOPs are moved around the network in a logical manner based on network loadings to release capacity

•Interaction with an 11kV fault demonstrated

Successful outcomes

Click on the figure below to review the Active HV solution

Map of central London primary substations with interconnected LV networks

90

The following sites in LPN were shortlisted sites for Trial 1:

Trial 1 Site Selection Main MenuTrialsTrial 1

Durnsford Road – SW Feeder Group

Dukes Ave – W Feeder Group

Trinity Crescent – NE Group

Trinity Crescent – SE Group

Trinity Crescent – NW Group

Dukes Ave – NE Group

Dukes Ave – N GroupProposal of the final trial designs and installation

requirements

Development of the trial design and installation requirements in consultation with the Project Technical Design Authority

Installation of monitoring equipment to gather loading data from secondary transformers

Site visits to assess the secondary substations

The process for selecting the final site for Trial 1 is:

91

Trial 1 Site Selection: Preferred Site Main MenuTrialsTrial 1


Stage 1

Modelling HV switching with historical data

Stage 2

Modelling HV switching with

live data

Stage 3

HV switching in open loop control

(control room)

Stage 4

HV switching with automatic control

The following “Load Related Modes” will be demonstrated:

• Feeder Balance – to maximise the available capacity across the group.

• Feeder Demand Reduction – to determine the ability of a feeder to accept a new connection by understanding the effect on the rest of group as a result of the selected feeder having reduced available capacity.

• Group Demand Reduction – to determine the ability to reduce the demand on a Primary substation, to asses’ optimal running arrangements under Primary transformer outage conditions.

• Simulated Loading – to simulate the performance of the network various load profiles for sensitivity analysis

TRIAL 1

Trinity

Crescent

Primary s/s

LPN

Q4 2019

92

TRIAL 1 RESULTSContent not yet available

Main MenuTrialsTrial 1

93

Trial 2:

Network

Optimise

Trial Design


Main MenuTrialsTrial 2: Network Optimise

94

Advanced Automation and Optimisation will be applied to the HV and LV networks in combination. Soft open points, remote

controlled circuit breakers and link box switches will be used to reconfigure the LV network. The trial will demonstrate the

benefits of the active reconfiguration of networks, by releasing capacity for new connections.

Design for Trial 2: Network Optimise

•Radial 11kV network with 3 or 4 source feeders from the same Primary Substation

•Diversity of load profiles on the feeder group so there is scope to share load between feeders

•Some sites/feeders should be heavily loaded during some periods

•LV Networks should be arranged radially

•It should be possible to reconfigure the LV network, via the use of remote controlled link box switches and circuit breakers and/or SOPs, such that all HV network configurations are achievable

•LPN groups in central London (see map for Trial 1) which are interconnected should be excluded because open points provide first HV outage support

•Remote HV switching possible at a fair proportion of sites in the group

•There should be good interconnection to other load groups on the same primary substation, to allow for the simulation of rapid changes in load if required

•There should not be any large customer connections (e.g. hospitals or large single users) or IDNOs with loads sensitive to network switching or where supplies are critical

•Requirements

•Network Configuration

•Feeder/site loadings for 12 months

•Equipment types


•HV & LV NOPs are moved around the network in a logical manner based on network loadings to release capacity

•Interaction with faults demonstrated

•Hardware tested

Successful outcomes

Click on the figure below to review the Combined Network Optimise solution


95


Trial 2 Site selection


Dukes Ave – W Feeder Group

Trinity Crescent – NE Group

Trinity Crescent – SE Group


Dukes Ave – NE Group

Dukes Ave – N GroupProposal of the final trial designs and installation

requirements

Development of the trial design and installation requirements in consultation with the Project Technical Design Authority

Installation of monitoring equipment to gather loading data from secondary transformers and LV feeders

Site visits to assess the suitability of the on-street locations, secondary substations, LV boards, link boxes etc.

The process for selecting the final site for Trial 2 is:


96

Trial 2 Site selection: Preferred Site



Durnsford

Road

Primary s/s

• Trial 2 has the increased complexity of multiple

remotely controllable devices on the LV network

that require installation and ANM coordination

• Full surveys of all linkboxes required to determine

suitability of new devices

• Final scheme design pending full survey findings

Detailed investigations and site surveys have

been undertaken to identify locations for the LV

and HV devices and ensure suitability of site.

Stage 1

Modelling LV & HV switching + SOP

operation with historical data

Stage 2

Modelling LV & HV switching + SOP operation with live data

Stage 3

Online HV switching in open

loop control

Stage 4

Online LV switching in open

loop control

Stage 5

Online SOP optimisation in

open loop control

Stage 6

Full LV and HV network optimisation

with automatic (closed loop) control

TRIAL 2

LPN

97



98

Trial 3:

Primary

Connect

Trial Design


Main MenuTrialsTrial 3: Primary Connect

99

Primary Connect will trial a soft power bridge and demonstrate direct connection between two primary substations. The trial

will show the ability of the soft power bridge to release network capacity by managing primary substation peak demands.

Design for Trial 3: Primary Connect

• The two primary substations selected should be fed from the same grid supply point (GSP) and bulk supply point (BSP)

• Load profiles of the two primary substations should be complementary and require load transfers in both directions

• Primary substations should each have a firm capacity of less than 75MVA, so that 5MVA transfers (the power rating of the SPB) would be expected to have a noticeable effect

• It would be advantageous if at least one of the selected primary substations was experiencing or approaching a capacity constraint in the five-year data set detailed in the LTDS

•Requirements

• Primary substation loadings for 12 months

• Equipment types


• SPB successfully demonstrates bi-directional transfers between primary substations to release capacity

• Interaction with faults demonstrated

• Hardware proven

Successful outcomes

Click on the figure below to review the Primary Connect method


100

EPN was selected for Trial 3 so that Active Response trials could cover more than one licence area. This is to ensure that the methods are widely applicable.

Trial 3 Site selection: Preferred Site

South Stevenage and East Stevenage sites in EPN were selected for Trial 3

EPN

Stage 1

Simulating SPB optimisation with historical data

Stage 2

Simulating SPB optimisation with live data

Stage 3

Active SPB optimisation with manual control

Stage 4

SPB optimisation with automatic control

TRIAL 3 Q2 2020


101

Example load profile demonstrating the complementary profiles at the South and East Stevenage sites.

Trial 3 Site selection: Preferred Site Main MenuTrials

Transfers from East Stevenage to South Stevenage are shown as positive, and transfers from South Stevenage to East Stevenage

as negative.

• South Stevenage exhibits a commercial/industrial-type load profile with a peak on this day during office hours of around 67% of its firm capacity.

• East Stevenage represents a typical domestic profile with an evening peak of 61%.

• The SPB could reduce the peak loading at South Stevenage, from 67% during the day down to 53%. The equalised loading would reach a maximum of 60% at 17.00.

Trial 3

102



103

Trial 4:

Active

Response

Trial Design


Main MenuTrialsTrial 4: Active Response

104

Bringing together the Network Optimise and Primary Connect methods to demonstrate Active Response in a combined solution.

This will enable the complete solution (optimisation of primary substation loadings, HV network configuration and LV network configuration) to be trialled to

prove that the technologies operate in conjunction with each other to maximise the benefits.

Design for Trial 4: Active Response

• Combined requirements from Trial 2: Network Optimise and Trial 3: Primary Connect

•Requirements

• Network Configuration

• Primary substation, feeder and site loadings for 12 months

• Equipment types


• Interactions between solution elements confirmed and capacity released

Successful outcomes

The layout shown is for illustrative purposes only and does not

necessarily represent any of the actual sites considered


105


Trial 4 Site selection

Farjeon Road and Eltham High Street

1.Bengeworth Road and North Cross Road

1.Durnsford Road and Trinity Crescent

Durnsford Road and Dukes Avenue

• The most promising location has been identified as the Durnsford Road and Trinity Crescent primary

substations.

• The secondary site, 07693 Riverside Road, has been identified as having suitable space for installation of

an SPB.

• Further detailed investigations will now be undertaken to ensure the suitability of the sites. Should any

insurmountable issues be discovered during stage 4, the process will revert to the shortlisted sites to find

an alternative location.


LPN

SPBDurnsford

Road

Trinity

Crescent

106



107


End of Trials Section

Back to Main Menu

Back to Trials Menu

108

Use

Cases

Overview

Main Menu

Use Case Actors

Use cases menu

Concept DiagramsUse Case Summary

Use Case Steps

109

Use Case Overview

110

Introduction to Use Cases Main MenuUse Cases

Use Case <noun> A description of the possible sequences of interactions between the system under discussion and its external

actors, related to a particular goal.1

1. Reference: Cockburn, A. Writing Effective Use Cases. Addison-Wesley, 2001.

Actors

• Users that interact with a system

System

• A specific sequence of actions and interactions

• Also be referred to as a “scenario”

Goals

• The end result of most use cases

• Activities and variants used to reach the objective of the use case

The aim of the Use Cases is to describe the functionality and requirements with respect to needs of the actors

Actors must be external users that produce or consume data that are affected by the Use Case, such as:

• People/roles/job functions

• Systems

• Databases

• Organisations

• Devices

111

Summary of Active Response Use Cases Main MenuUse Cases

19 Use

Cases

7 Categories

11 Actors68 Unique

Steps

Design 11 Steps

Implementation 19 Steps

Operation - Hardware 18 Steps

Operation - Software 17 Steps

Review 3 Steps

•Initial Design Stage

Detailed Design Stage

Operation Stage

Network Optimise

Primary Connect

SPB/SOPs

Protection

Categories cover

different implementation

stages and operational

processes

Actors are the

systems and

roles involvedIndividual steps

that make up a

Use Case

112

Use Case Description

1. Use Case Diagrams

Designed to illustrate the interactions between

Actors and Steps of the Use Case.

2. Tables

Provide further details of the Steps, where required.

The Use Cases are presented as follows

Main MenuUse Cases

113

Use Case Example

Actor 1

Actor 2

Step 1

Step 3

Common

step for

multiple use-

cases

Step 2

Optional step

2.2

Optional

step 2.3

Optional step 2.1

Step 4

Optional step

Mandatory step

Trigger: The text in this box describes what will trigger the use-case

Optional step

2.2.1

Optional step

2.2.2

Actor 3

Actors are shown in a column

on the left (with Initiating Actor

shown on top)

Level 1 steps in the basic

flow (from top to bottom)

Level 2 steps in the basic

flow (extending from Level 1)

Actor/s influenced by steps

AND/OR Level 3 steps in the

basic flow

Actor-step interactions- Active Response process

(with link to explanation).

- Outline colour indicates

implementation stage

Trigger Design

Implement Review

KEY

Main MenuUse Cases

114

Use Case Actors

Main MenuUse Cases

115

Business-as-Usual Actors

People/Roles

Control Engineers

Network Planners

Outage Planners

Operational Planners

(new DSO role)

Field Engineers

Software

Advanced Automation and Optimisation

System (within ANM)

The Advanced Distribution

Management System (ADMS)

Automated Restoration Systems

Hardware

Remote Terminal UnitsIntelligent Device

Controllers (controlling the PEDs)

Protection System

The interactions between these Actors are summarised on the next page

Main MenuUse Cases

116

Actor Summary & InteractionsAutomated Restoration

Schemes

Network Planners

Remote Terminal Units

The Advanced Distribution

Management System (ADMS)

Protection System

Intelligent Device Controllers

Advanced Automation and

Optimisation System*

Field Engineers

Operational Planners*

Control EngineersOutage Planners

Key

Person / role Software Actor Hardware Actor

Network Operation Interactions

Planning Interactions

Delivery Interactions

Interaction to be

determined

* New or future

Actor within UKPN New Actor required for

Active Response

Click Actor for description

Main MenuUse Cases

117

Actor Element Description

Actor Name Control Engineers

Actor Type Job role / team of people

Actor Description Control Engineers control, operate and maintain the network

Interactions with other

Primary Actors

• Advanced Distribution Management System (ADMS) Actor to receive information about the network and change the network

configuration

• Network Planners

• Outage Planners

• Operational Planners`

• Commissioning Engineers


Secondary Actors

• Incident Dispatchers (manage fault restoration / repairs and intermediate between control engineers and the actual customers)

• Field Engineer

Actor Objectives • Keep supplies on

• Ensure the network is operated in a safe condition

• Responded to any system faults in the network reported by the ADMS or a customer

• Carry out agreed switching schedules to make network portions safe for working on, and issue / cancel permits to work

Actor Triggers • Planned outages (to upgrade or repair the network)

• Planned network reconfiguration

• Alarms from the Advanced Distribution Management System (ADMS)

• A predicted (off-supply) incident from the ADMS to be confirmed by the Field Engineer that a non-telemetered protection device has

operated

Control Engineers Main MenuUse CasesActors

118


Actor Name Network Planners


Actor Description Network Planners includes the new connections teams and previously the distribution planners and infrastructure planners. Network

Planners are responsible for designing how New Connection requests can be accommodated within the existing networks and identifying

any immediate reinforcement work that will be required to enable the network to accommodate particular connection requests while still

maintaining network integrity and continuity of supply within the limits imposed by planning standards (P2-6). Once the connection offer

has been accepted, the Outage Planners determine how to facilitate the investment and the Control Engineers reconfigure to allow the

new customer to be connected.

Network Planners are also concerned with the strategic development of the network over a number of planning horizons and planning

over these horizons to prepare for future growth of generation and load. They identify parts of the network which require upgrade due to

aging assets or predicted load growth (e.g. major planned developments) and set-up a business case to replace those assets. NAMP

plans produced by Ofgem. Once the investment has been decided, the Outage Planners determine how to facilitate the investment and

the Control Engineers reconfigure to allow the changes.


Primary Actors

• Control Engineers

• Outage Planners

• Optimisation Platform (understand capacity available on the network)


Secondary Actors

• New connection requests

• Software models to forecast network load growth

• EHV planning/modelling software

• Distribution planning software to design and reinforce the network

Actor Objectives • Design the network to facility customer connections

Actor Triggers • A new connection request

• The Control Engineers identify a problem with the network for example a repeated fuse operation

Network Planners Main MenuUse CasesActors

119


Actor Name Outage Planners


Actor Description Outage Planners plan for system outages when network maintenance is required or network upgrades are required. They are passed

work plans and develop switching schedules and project plans to undertake the work determined from the Network Planners. They

perform contingency analysis for if a network fault were to occur during planned outage and are responsible for scheduling outages so

that sufficient network security is maintained at all times.


Primary Actors




Secondary Actors

• Contingency Software

• Upgrade project teams

• Innovation / Network Development project teams

Actor Objectives • Plan how to perform upgrades to the network and undertake maintenance on the network by disconnecting as few customers as

possible for as little time as possible.

Actor Triggers • Reinforcement works identified by the Network Planners when a customer has accepted a connection offer or network investment is

required.

Outage Planners Main MenuUse CasesActors

120


Actor Name Operational Planners


Actor Description This is a new role envisaged for when the DNO becomes a DSO.


Primary Actors


• Optimisation Platform


Secondary Actors

• TSO

• Network customers and/or aggregators selling services

Actor Objectives • Manage the markets used to buy services to operate the distribution network.

• Manage the process of selling services to the TSO.

• Manage the settings for the active equipment operating on the network. For example manage the optimisation parameters used in the

ANM.

Actor Triggers • Organise markets when a new service is required by the DSO for example if storage is required to add capacity to the network.

• Respond to service requests from the TSO and determine if the DSO is able to sell a service.

• Service requests from the Control Engineers about any problems with the intelligent network systems.

Operational Planners Main MenuUse CasesActors

121


Actor Name Field Engineers


Actor Description Commissioning Engineers set-up new equipment connected to the network and check that the equipment is operating correctly. They

check that all connections to the equipment are correct for both the electrical connections and the data connections. Checks are

completed to ensure that the equipment is receiving all necessary data and sending all necessary data. The ADMS may be used to

visualise the output of the hardware to the Commissioning Engineer.


Primary Actors


• The Advanced Distribution Management System (ADMS)

• Remote Terminal Units

• Protection System

• Intelligent Device Controllers


Secondary Actors

• Equipment manufactures

• Upgrade project teams

Actor Objectives • Ensure all new equipment is correctly connected to the network and will operate as expected.

Actor Triggers • After a new piece of equipment has been installed but prior to commissioning.

• After maintenance has been undertaken on the network.

Field Engineers Main MenuUse CasesActors

122


Actor Name Advanced Automation and Optimisation System

Actor Type System

Actor Description The advanced automation and optimisation system (part of the new Active Network Management platform) performs the necessary

calculations to determine the running arrangement of the network and operate the intelligent power electronic devices. The optimisation

platform requires information about the equipment in the network, the voltages of the network and the power flows in the network.


Primary Actors

• Advanced Distribution Management System (ADMS)

• Operational Planners



Secondary Actors

• None

Actor Objectives • Its aim is to operate the network such that an optimisation criteria is met without exceeding any of the constraints. The optimisation

criteria could be to maximum capacity or minimise losses.

Actor Triggers • An identified constraint in the network has been exceeded.

• The network is operating in a sub-optimal configuration.

• There has been a significant change in the network load or generation.

• There has been a change in the topology of the network, for example a fault has occurred and a section of network has been isolated.

Advanced Automation and Optimisation System (new role)

Main MenuUse CasesActors

123


Actor Name Advanced Distribution Management System (ADMS)

Actor Type System

Actor Description The ADMS is the interface between the physical assets in the network and the Control Engineers. The ADMS may also have some

autonomous operations such as automated restoration after faults which it may perform when a trigger is received.


Primary Actors



• The Optimisation Platform

• Automated Restoration Schemes

• Remote Terminal Units


Secondary Actors

• Incident dispatchers

• Fault calls from customers and other sources

• [Near Future] Last-gasp/first-breath reports from Smart Meters

Actor Objectives • Maintain the current live network state in real time

• Visualise the state of the network

• Manage permits to work on the network after validating that the safety rules are correctly followed and the network has been switched

to a safe state to allow work to occur.

• Enable the Control Engineers to operate the assets within the network

• Manage switching schedules for planned outages and other network reconfiguration.

• Enable the optimisation algorithm to gather information about the network and enable the Optimisation algorithm to configure the

network.

Actor Triggers • A “digital” alarm from a network asset.

• A report from a RTU about an unsolicited operation of a circuit breaker.

• Data from a network asset.

• An action from the Network Engineer. This might be a request for information or a command to operate an asset within the network.

• An action from the Optimisation Algorithm.

Advanced Distribution Management System

Main MenuUse CasesActors

124


Actor Name Automated Restoration Scheme

Actor Type System

Actor Description The Automated Restoration System restores healthy sections of the network once the protection has operated to isolated a faulted

section of cable or a faulted asset.


Primary Actors


• Possible commands to Intelligent Device Controllers


Secondary Actors

• None

Actor Objectives • Restore as many customer supplies as possible within a minute of an EHV/HV fault.

Actor Triggers • After the operation of a protection device has been reported via an alarm to the ADMS via the relevant RTU.

Automated Restoration Scheme Main MenuUse CasesActors

125


Actor Name Protection System

Actor Type Hardware

Actor Description The Protection System constantly monitors the network to detect any fault currents or mal-operation of the network. Upon detection, the

protection device will operate to disconnect the faulted section of network.


Primary Actors

• Remote Terminal Units (RTUs)



Secondary Actors

• None

Actor Objectives • Maintain integrity of the network any remove any assets from the network which are not operating correctly.

Actor Triggers • When a network measurement (for example, voltage, current, power) goes outside the allowed operating region.

• When a trip signal is received from an inter-trip connection.

Protection System Main MenuUse CasesActors

126


Actor Name Remote Terminal Units (RTUs)

Actor Type Hardware

Actor Description Remote Terminal Units interface substation equipment with the ADMS. RTUs act as the substation gateway and in future will act as a

router to coordinate the substation data network. The latest RTUs have the ability to have programmed logic to do specific things in

predefined circumstances.


Primary Actors


• Protection Systems (indirect, the protection system will cause a circuit breaker to trip which the RTU will then see via its telemetry)

• Intelligent Device Controllers



Secondary Actors

• Other ancillary site equipment

Actor Objectives • Pass messages from the ADMS to the correct device

• Operate switching devices when commanded to from the ADMS

• Report to ADMS information from any substation measurement equipment or other devices connected to the network

• Report any alarms raised by the protection equipment

Actor Triggers • Unsolicited operation of a protection device (CB trips).

• Data from measurement sensors or other devices connected to the substation network, including digital “alarm” signals.

• Commands from ADMS to open or close switches.

• Any messages from ADMS intended for other devices on the substation network

• Failures of the communications link to the ADMS.

Remote Terminal Units Main MenuUse CasesActors

127


Actor Name Intelligent Device Controllers

Actor Type Hardware

Actor Description Intelligent Device Controllers are situated within controllable devices and have the ability to make their own decisions or follow

instructions from the ADMS.


Primary Actors

• Remote Terminal Units (RTUs)



Secondary Actors

Actor Objectives • Operate the controllable devices

• Execute any functions they have been programmed with

• Follow any instructions from the ADMS which are sent via the RTU

Actor Triggers • Instructions from the ADMS

• Measurement data local to the device

• Measurement data remote to the device

Intelligent Device Controllers Main MenuUse CasesActors

128

Selected Concept Diagrams

Main MenuUse Cases

129

New

Connection

Request

Perform Initial

Assessment

Asses Issues

and identify

most cost

effective

solution

Operate

and

Monitor

solution

Feedback loop – check that the solution is accommodating the new connection

Concept for UC1: New Connection Would Breach Network Limits



If periodic network

reconfiguration can

solve the constraints

Primary ConnectIf support from another primary

substation is required

Traditional

Reinforcement


possible

TOOLBOX OF

POTENTIAL SOLUTIONS

Active Response Solutions

Active HV

Active LV

Secondary Connect

Active HV + Active LV

Main MenuUse Cases

130

Identify network

constraintMonitor network

& build / update

network model

Asses Issues

and identify

most cost

effective

solution

Operate

and

Monitor

solution


Concept for UC2: HV/LV Network Issue



If periodic network

reconfiguration can

solve the constraints

If support from another primary


Traditional

Reinforcement


possible

TOOLBOX OF

POTENTIAL SOLUTIONS


Primary Connect

Active HV

Active LV

Secondary Connect

Active HV + Active LV

Main MenuUse Cases

131

Identify primary

substation

overload

Monitor network

& build / update

network model

Asses Issues

and identify

most cost

effective

solution

Operate

and

Monitor

solution


Concept for UC3: Primary Substation Overload



Primary ConnectIf support from another primary


Traditional

Reinforcement


possible

TOOLBOX OF

POTENTIAL SOLUTIONS

Active Response Solution

Main MenuUse Cases

132

Swinging load

group identifiedModel to assess

regime

economics

Operate

and

Monitor

solution


Asses Issues

and identify

most cost

effective

solution

Pri A Pri B

Concept for UC4: Swinging Load Group



Traditional

Reinforcement


possible

TOOLBOX OF

POTENTIAL SOLUTIONS


Active HV

Main MenuUse Cases

133

Use Case Summary Tables

Main MenuUse Cases

134

Use Case Summary

Use Cases diagrams describe the implementation processes and the operational functions

Implementation process

or operational function

Use Case Name

Initial Design Stage UC1: New Connection Would Breach Network Limits

UC2: HV/LV Network Issue

UC3: Primary Substation Overload

UC4: Swinging Load Group

Detailed Design Stage UC5: Detailed design of Active Response hardware and software

UC6: Detailed installation of Active Response hardware and software

Operation Stage UC7: Planned Network Outage

UC8: Visualise Active Response Status

Network Optimise UC9: Network Optimise – Active HV

UC10: Network Optimise – Active LV

UC11:Network Optimise – Secondary Connect

Primary Connect UC12: Primary Connect

SPB/SOPs UC13:Enable SPB / SOP

UC14: SPB / SOP Operates

UC15: Support from the SOP / SPB not required

UC16: Disable SPB / SOP

Protection UC17: Fault detected on the SOP/SPB

UC18: Fault on the HV network

UC19: Fault on the LV network with link box switches

Main MenuUse Cases

Full information

in embedded

document

135

Category Table Number Use Case Name

Design

T.DN.01 Initial site assessment

T.DN.02 Assess operating regime and economics

T.DN.03 Design solution

T.DN.04 Offer least cost solution to customer

T.DN.05 Accepted connections request

T.DN.06 Design of the Active Response solution

T.DN.07 DSR or other

T.DN.08 Design reinforcement

T.DN.09 Primary Substation Assessment

T.DN.10 Detailed design of the Active Response solution

T.DN.11 Substation civil works design

Implementation

T.IM.01 Handover Meeting

T.IM.02 Handover of initial design documents

T.IM.03 Handover of approved investment paper

T.IM.04 Outage planning

T.IM.05 Highway planning

T.IM.06 Build and commission Active Response solution

T.IM.07 Network outages

T.IM.08 Tender DSO services from market

T.IM.09 Configuration into ADMS

T.IM.10 Active Response parameter design

T.IM.11 Field testing

T.IM.12 Field test Active Response

T.IM.13 Repair / upgrade of network

T.IM.14 Energise network in ADMS

T.IM.15 Download intelligent device logs

T.IM.16 Switching schedule development

T.IM.17 Generate switching schedule

T.IM.18 ADMS patch development

T.IM.19 Apply ADMS Patch

Operation -

Hardware

T.OH.01 Enable SPB / SOP command received

T.OH.02 Disable SPB / SOP command received

T.OH.03 SPB / SOP operates

T.OH.04 Set-point control

Use Case Steps

Individual steps that make up the overall Use Cases provide more detailed information

Main MenuUse Cases

Category Table Number Use Case Name

Operation -

Hardware

(continued)

T.OH.05 Voltage support

T.OH.06 Voltage imbalance compensation

T.OH.07 Voltage harmonic compensation

T.OH.08 SPB / SOP detects voltage dip or rise

T.OH.09 Fault ride-through

T.OH.10 SPB disconnects

T.OH.11 SOP disconnects

T.OH.12 Network health monitoring

T.OH.13 RTU collects network data

T.OH.14 RTU reports protection operation

T.OH.15 RC circuit breaker detects fault & operates

T.OH.16 Link box detects fault

T.OH.17 Link boxes operate to restore supplies

T.OH.18 SPB/SOP report to RTU

Operation -

Software

T.OS.01 Enable Active Response

T.OS.02 Disable Active Response

T.OS.03 Visualise Active Response status

T.OS.04 Forecasting the network loading

T.OS.05 State estimation

T.OS.06 Power flow calculation

T.OS.07 Identify optimal running arrangement

T.OS.08 Reconfigure HV network

T.OS.09 Reconfigure LV network

T.OS.10 Action under fault condition

T.OS.11 Coordination with APRS

T.OS.12 Coordination with PORT

T.OS.13 Isolate network in ADMS

T.OS.14 SPB / SOP operation calculated

T.OS.15 SPB / SOP not required

T.OS.16 Enable SPB / SOP command sent

T.OS.17 Disable SPB / SOP command sent

ReviewT.RV.01 Review operating regime and economics

T.RV.02 Gather lessons learnt

T.RV.03 Report on operational performance

Full information

in embedded

document

136


End of Use Case Section

Back to Main Menu

Back to Use Cases Menu

137

Operational

Requirements

Overview

Main MenuOperational Requirements Menu

138

Operational Requirements Overview

Main MenuOperational

Requirements

139

OPERATIONAL REQUIREMENTSContent not yet available

Main MenuOperational

Requirements

140

Analysis

Algorithms

Overview

Main MenuAnalysis Algorithms Menu

141

Analysis Algorithms Overview

Main MenuAlgorithms

142

ANALYSIS ALGORITHMSContent not yet available

Main MenuAlgorithms

143

IT/OT

Solution

IT/OT Architecture

Data Transmission Options

Main Menu

IT/OT Requirements

IT/OT Solution Architecture

Principal real-time components

144

IT/OT Architecture

Main MenuIT/OT Solution

145

Control hierarchy concept

Data historian

Network planning

tools

GIS database

Key:

Advanced Automation and Optimisation System (within ANM software)

State estimation Power flowOperational

forecasting (24h)Optimisation Power Potential platform

Advanced Distribution Management System (ADMS) LV network model

Controllable

DERs / DSR

Unified Power

Flow Controller

PowerFul CB

Quad Booster

Real Time

Thermal Ratings

SSTSPB

SOPSmart

Link Box

LV

Circuit BreakerControl

Information

New solution

Smart device

This slide shows how the Active Response solution has a centralised control approach, where information is exchanged between the Advanced

Automation and Optimisation System (within the ANM software) and the ADMS so that the DMS has visibility of the entire network.

Monitored

asset

Acronyms are defined in the glossary of terms


Contingency

analysisFault levels

146

This allows the Control Team to maintain visibility and control of the network

at all times

The Control Team can accept/reject the actions of the Advanced Automation and Optimisation System

(e.g. for maintenance and fault restoration)

The ADMS is able to check for operational restrictions

before executing the switching proposed by the Advanced Automation and

Optimisation System

Reasons for Selecting Centralised Control

Active Response will use a centralised approach where the Advanced Automation and Optimisation System

receives the network model and information from the ADMS and passes switching operations to the ADMS.

• Active Response will require a network model (feeder locations, lengths, impedances and ratings). This

information requires a high bandwidth connection to a database.

• Passing this information to agents in the field, would be slow over the existing infrastructure.

• Active Response can receive all the required information over a high bandwidth connection if a centralised

approach is taken.

Other control approach options were considered and are discussed in Project Deliverable 1. The following

slides discuss the concept in more detail.


http://innovation.ukpowernetworks.co.uk/innovation/en/Projects/tier-2-projects/active-response/Project-Documents/Active+Response+-+Project+Deliverable+1+report+v1.0+15082018.pdf

147

Centralised approach through DMS

• The ADMS is ultimately responsible for the control of the distribution network.

• All devices communicate with the ANM software through the ADMS and the ADMS is able to intervene where necessary.

• A state space estimation is performed to determine areas which have no measurement and to verify / make corrections to measurement

data. Measurement / calculations of all nodes in the network are passed to the ANM software. (Estimation could happen in the ADMS, if

possible, or in the ANM software).

• The Advanced Automation and Optimisation System performs the optimisation and determines the network configuration and operation of

the SOPs / SPBs by sending commands through the ADMS.

• Commands could be sent in real time or a schedule sent with change requests sent when necessary. SOPs and SPB would follow desired

profile but not necessarily be making decisions about the profile.

Data historian

Advanced Distribution Management System (ADMS)

SOPSSTM LB SPB

RTU

RMU

Key:

Control

Information

New solution

Smart device

Measurement

location

Future

technology

SOPSSTM LB SPB

RTU

RMU

Advanced Automation and

Optimisation System (within ANM) Advantages of Centralised Approach

The Advanced Automation and Optimisation System

and DMS have visibility of all the devices and

information about the network for decision making

Disadvantages of Centralised Approach

A communication failure could prevent the solution

from operating. Large quantity of data travelling to a

single location. There may be stability issues.


Acronyms are defined in the glossary of terms

148

Detailed SGAM

This is a Smart Grid Architecture

Model (SGAM) diagram of the

Active Response solution, which

shows how it interacts with the

wider UK Power Networks’ IT/OT

systems.

It is taken from Figure 14 in Project

Deliverable 1, where detailed

commentary is provided.


http://innovation.ukpowernetworks.co.uk/innovation/en/Projects/tier-2-projects/active-response/Project-Documents/Active+Response+-+Project+Deliverable+1+report+v1.0+15082018.pdf

149

Principal real-time components


150

Overview of Principal Components Main MenuIT/OT Solution

The principal real-time building blocks within the Active Response advanced automation and optimisation

system are:

Active Response

Forecasting

State estimation

Power flowContingency

analysis

Optimisation

To compute accurate demand and generation data for use in calculating power flows over the immediate time horizon (within 24 hours). This data ensures optimisation decisions account for future network states, in order to minimise the number of switching actions performed throughout the day.

To estimate measurement values for locations on the network where no real-time or historical measurement

values are available or where available values appear suspect due

to transducer or data acquisition failures.

To calculate the actual or projected power

flow within the network based on current,

historical or forecast loadings and

embedded generation inputs

To calculate the power flow results under

various contingency scenarios, which might

be considered as potential faults which

occur on the system. It will be important that

the optimisation solution considers the

impact of various contingencies and does

not recommend network configurations

which put the network at risk.

To compute the most effective

running arrangement for the network

for a selected optimisation cost

function, including the optimal levels

of power transfers through the SOPs

and SPBs, and sends appropriate

instructions to the ADMS, which

controls the network assets, to

achieve these new running

arrangements

151

Data Transmission OptionsThis section explores the options for the data which is sent and received by devices and the Active Response solution. It explores the uses of data compression, and extracting information by profiling the data. How the data is sent is important for optimising the communication, reducing latency and ensuring communication resilience.


152

Time series data

Smart

M

RTU

RTU

0

1

2

3

4

5

6

0 5 10 15 20 25

Data

poin

t

Sample

• In a time series data design, the devices send and receive data as and when it is generated. The interval may be fixed, for

example, once per second, once per minute or once per half-hour. Or the interval may be variable, for example, data is sent

when a measurement changes by a specified amount.

• This method of sending data is analogous to a bitmap image or wav file for music. There is no data compression.

• This may create a lot of data traffic and a high bandwidth may be required. It is noted that a variable rate often creates

much less data traffic.

• If there is an issue with the communications link, the data points are lost. If this data is required by smart devices, a loss of

data strategy is required.

• If there is local data storage, a handshaking arrangement could enable the data to be requested to be retransmitted.

Time series data

Key:

Control

(wireless link)

Information

(wireless link)

New solution

Smart device

Measurement

location

ARActive

Response

Module

Control

(wired link)

Information

(wired link)

Time series data can be sent at a specific sampling rate,

or at a variable rate according to the amount of change

of the measurement.

Time series data can apply to any source of data, for

example set-points and measurements.


153

Compressed data

M

RTU

• Time series data is sent over a short cable connection to a compressions algorithm

The compression algorithm could be incorporated into the smart device, measurement, RTU or be a separate

“box” which receives the time series data and compresses it ready for communication.

• This method of sending data is analogous to a jpeg or mp3.

• The amount of data traffic is reduced, however the latency may be increased.

• There are many compression techniques available and this presentation does not consider the merits of different

compression techniques.

• If there is an issue with the communications link, the data points may be lost. If this data is required by smart devices,

a loss of data strategy is required.

• If there is local data storage, a handshaking arrangement could enable the data to be requested to be retransmitted.

Compression /

decompression

algorithm

Compression

algorithm

RecipientDecompression

algorithm

Smart

Time series data Compressed data

Time series dataCompressed data

Key:

Control

(wireless link)

Information

(wireless link)

New solution

Smart device

Measurement

location

ARActive

Response

Module

Control

(wired link)

Information

(wired link)

RTU

Compression algorithm could be part of the smart

device, RTU or a separate “box” which connects to the

gateway router

Compression

algorithm

Control data flow not shown but

any large data volumes could

be compressed

Interface between data types




154

Data profiling / estimation

• Time series data is sent over a short cable connection to a profiling algorithm.

The profiling algorithm could be incorporated into the device or be a separate “box” which receives the time

series data and compresses it ready for communication.

• The profiling algorithm extracts information about the data stream and matches the time–series data to a profile.

The algorithm will require data storage to provide an accurate match to a profile, or advise that a new profile is

required.

• The amount of data traffic is reduced and there should be no impact on the latency. As soon as the profile changes,

information about the new profile is sent to the recipient.

• The recipient reconstructs the time series data from the information about the profile. If no data is received, it can

estimate the next data point assuming that the profile of the data has not changed.

• This technique should prevent an unreliable communication link from causing hardware to stop working.

• There may be small errors between the time series data and the estimate data point.

Key:

Control

(wireless link)

Information

(wireless link)

New solution

Smart device

Measurement

location

ARActive

Response

Module

Control

(wired link)

Information

(wired link)

M

RTU

Profile /

expansion

algorithm

Compression

algorithm

RecipientExpansion

algorithm

Smart

Time series data Profiled data

Time series data Profiled data

RTU

Profile algorithm could be part of the smart device,

RTU or a separate “box” which connects to the

gateway router

Profile

algorithm

The profiles may be need to be

expanded. They can be saved as

profiles and mathematical

operations performed on the profiles

Profile algorithm matches the pattern

of the time series data to a profile

number and profile magnitude




155

Approach Advantages Disadvantages

Time series data Simple to implement Large volumes of data, loss of

data if the communications fails

Compressed data Smaller data flows Increase in latency due to

compression

Data profiling / estimation Minimal data flows Potential error if profile is

incorrect, contingency required

when there is a system event

Data Transmission Conclusions Main MenuIT/OT Solution

156

• Not all data needs to be sent / collected as soon as the data is generated.

• Some data could be transmitted when there is available capacity in the communications networks.

• Some RTUs collect historical data in local storage and transmit daily. The transmission could happen over night when the communications networks have more capacity.

Real time vs non real time Main MenuIT/OT Solution

157

IT/OT Requirements


158

The requirements are categorised as follows:

How the IT/OT requirements have been presented


The IT/OT requirements describe what the Active Response solution needs to be able to do. They

have been defined to satisfy the needs of the Active Response project with UK Power Networks’ long

term IT/OT strategy in mind.

ANM Requirements

• Define the requirements of the Advanced Automation and Optimisation System, within the UK Power Networks’ enterprise Active Network Management software, which was being procured in 2018

• Further categorised as functional/non-functional

Non-ANM Requirements

• All of the IT/OT aspects that are not included in the Advanced Automation and Optimisation System

• Further categorised as functional/non-functional

The organisation of the ANM and Non-ANM requirements is summarised in the following slides.

159

Active Network Management Requirements

AN

M R

equ

ire

me

nts

(1)

General

Availability Non-functional

Configuration

Functional

Non-functional

Fail safety Functional

GeneralFunctional

Requirements

Maintainability Non-functional

Scalability Non-functional

User interface Functional

Data

Data Integration

Functional

Non-functional

Data Quality Functional

Data Retention Functional

Exporting Information

Functional

Measurement data

Functional

Network information

FunctionalA

NM

Re

qu

ire

me

nts

(2

)

Coordination, Control and Dispatch

Network Condition Management

Functional

Control Functional

Coordination Functional

Dispatch Functional

Fault Level Management

Functional

Safety Functional

Data & Cyber Security

Security Non-functional

User Access Non-functional

Analysis Functions

Fault Level Calculation Functional

Forecasting Functional

Load Flow Functional

LV Network Differences

Functional

Optimisation Functional

Simulation Functional

State Estimation Functional

System Performance

Non-functional

Functional


160

Non-ANM RequirementsN

on

-AN

M R

equ

ire

me

nts

(1

)

Distribution Planning

General Functional

Compliance with Design Standards

Functional

Load Flow Functional

Protection Studies Functional

Restoration Studies

Functional

PED Modelling Functional

Optimisation Modelling

Functional

User Interface

Functional

Non-functional

System Performance

Non-functional

Operational General Non-functional

Forecasting

General Functional

Real-Time and Near Future

Functional

Long Term Functional

No

n-A

NM

Re

qu

ire

me

nts

(2

)

Investment Planning & Modelling

Investment Planning & Modelling

Functional

ADMS

User interface Functional

General Functional

Data Integration Functional

Commissioning Functional

NetMAP

Interface Functional

Data Non-functional

Enterprise Asset Management

General Functional

Data Historian General Functional

Visualisation General

Non-functional

Functional

SCADA Asset Management

General Functional


161

End of IT/OT Solution Section

Back to Main Menu

Back to IT/OT Menu

162

OTHER INFORMATIONContent not yet available

Main Menu