active response storyboard - uk power networks€¦ · this storyboard is an up-to-date summary of...
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104/12/2019 1
ACTIVE RESPONSE STORYBOARD
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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.
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Introduction
Use Cases
Trials
Project Methods
Operational Requirements
Analysis Algorithms
Other information
Main Menu
ACTIVE
RESPONSE
User Guide
IT/OT Solution
Hardware
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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
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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
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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
3-Terminal Soft Open Point
Soft Power Bridge
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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
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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
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End of Section
Back to Main Menu
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Introduction
IntroductionProject Plan
Active Response at a glance
Main Menu
WorkstreamsProject Deliverables
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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
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Active Response Introduction
Main MenuIntroduction
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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
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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:
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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
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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.
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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
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• 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
Main MenuIntroduction
More on Methods
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• 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
Main MenuIntroduction
More on Method 2
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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
Main MenuIntroduction
Primary Connect
enabled by SPB
Network Optimise
comprising 3
solutions
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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
Main MenuIntroduction
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
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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
Main MenuIntroduction
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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
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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
Main MenuIntroduction
Workstream 1
Workstream 2
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Workstreams
Main MenuIntroduction
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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
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Project Deliverables
Main MenuIntroduction
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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
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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
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Project Plan
Main MenuIntroduction
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
Main MenuIntroduction
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Please select a link to continue and exit this section
End of Introduction Section
Back to Main Menu
Back to Introduction Menu
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Hardware
Soft Open Points
Conventional LV Equipment
Main Menu
Soft Power Bridge
Hardware Menu
Conventional HV Equipment
Overview
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Hardware Overview
Main MenuHardware
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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
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Soft Open Points
Main MenuHardware
37
2-Terminal Soft Open Point
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
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3-Terminal Soft Open Point
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
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Soft Power Bridge
Main MenuHardware
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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
Primary Substation 2
HV Busbars
Option 1: Interconnection
between substation busbars
Option 2: Interconnection
between HV networks
Normally Open Point
Secondary
Substation RMU
Soft Power Bridge
RMU for Soft Power
Bridge connection
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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.
Primary Substation 1
HV Busbars
Primary Substation 2
HV Busbars
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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
Input Enclosure With Triplex Cable
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
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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
Input Enclosure With Triplex Cable
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
Please select a link to continue and exit this section
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
Methods & Solutions Main Menu
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.
Network Optimise – Active HV Example (2)
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
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.
Network Optimise – Active HV Example (3)
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
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.
Network Optimise – Active HV Example (4)
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
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.
Network Optimise – Active HV Example (5)
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
19:00
TF & RMU
NOP
Heavily
loaded
Lightly
loaded
Key
Jump to Trial 1: Active HV
60
Network Optimise – Active LV
Methods & Solutions Main Menu
61
Active LV Concept Overview
Primary Substation
Secondary Substation RMU
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
Network Optimise – Active LV Example (2)
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
Network Optimise – Active LV Example (3)
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
Network Optimise – Active LV Example (4)
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
Network Optimise – Active LV Example (5)
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
Methods & Solutions Main Menu
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
Secondary Substation RMU
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
Network Optimise – Secondary Connect Example (2)
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
Network Optimise – Secondary Connect Example (3)
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
Network Optimise – Secondary Connect Example (4)
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 Equalisation
Transformer A Transformer B Transformer C
Equalised Time Reference
73
Network Optimise – Secondary Connect Example (5)
• 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
Methods & Solutions Main Menu
75
Network Optimise Comprising Active HV, Active LV & Secondary Connect
Primary Substation
Secondary Substation RMU
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
Methods & Solutions Main Menu
77
Primary Connect Concept Overview
Primary Substation 1
HV Busbars
Primary Substation 2
HV Busbars
Secondary Substation RMU Normally open point
Option 1: Interconnection
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
Transformer Equalisation
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 Connect Example (2)
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
Transformer Equalisation
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 Connect Example (3)
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
Transformer Equalisation
Primary A Primary B Equalised Time Reference
13:00
81
• Due to the different load profiles, in the evening, substation B becomes heavily loaded and substation A is lightly loaded.
Primary Connect Example (4)
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
Transformer Equalisation
Primary A Primary B Equalised Time Reference
19:00
82
• The SPB transfers power from Primary substation A to Primary substation B to reduce the peak load.
Primary Connect Example (5)
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
Transformer Equalisation
Primary A Primary B Equalised Time Reference
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
Trinity Crescent – NW Group
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
Site SelectionResults
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
Data required for Selection process
•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
Main MenuTrialsTrial 2
95
The following sites in LPN were shortlisted sites for Trial 2:
Trial 2 Site selection
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 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:
Main MenuTrialsTrial 2
96
Trial 2 Site selection: Preferred Site
Durnsford Road – SW Feeder Group
Main MenuTrialsTrial 2
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
TRIAL 2 RESULTSContent not yet available
Main MenuTrialsTrial 2
98
Trial 3:
Primary
Connect
Trial Design
Site SelectionResults
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
Data required for Selection process
• 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
Main MenuTrialsTrial 3
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
Main MenuTrialsTrial 3
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
TRIAL 3 RESULTSContent not yet available
Main MenuTrialsTrial 3
103
Trial 4:
Active
Response
Trial Design
Site SelectionResults
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
Data required for Selection process
• 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
Main MenuTrialsTrial 4
105
The following sites in LPN were shortlisted sites for Trial 4:
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.
Main MenuTrialsTrial 4
LPN
SPBDurnsford
Road
Trinity
Crescent
106
TRIAL 4 RESULTSContent not yet available
Main MenuTrialsTrial 4
107
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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
Interactions with other
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 Element Description
Actor Name Network Planners
Actor Type Job role / team of people
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.
Interactions with other
Primary Actors
• Control Engineers
• Outage Planners
• Optimisation Platform (understand capacity available on the network)
Interactions with other
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 Element Description
Actor Name Outage Planners
Actor Type Job role / team of people
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.
Interactions with other
Primary Actors
• Control Engineers
• Network Planners
Interactions with other
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 Element Description
Actor Name Operational Planners
Actor Type Job role / team of people
Actor Description This is a new role envisaged for when the DNO becomes a DSO.
Interactions with other
Primary Actors
• Control Engineers
• Optimisation Platform
Interactions with other
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 Element Description
Actor Name Field Engineers
Actor Type Job role / team of people
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.
Interactions with other
Primary Actors
• Control Engineers
• The Advanced Distribution Management System (ADMS)
• Remote Terminal Units
• Protection System
• Intelligent Device Controllers
Interactions with other
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 Element Description
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.
Interactions with other
Primary Actors
• Advanced Distribution Management System (ADMS)
• Operational Planners
• Network Planners
Interactions with other
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 Element Description
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.
Interactions with other
Primary Actors
• Control Engineers
• Commissioning Engineers
• The Optimisation Platform
• Automated Restoration Schemes
• Remote Terminal Units
Interactions with other
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 Element Description
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.
Interactions with other
Primary Actors
• The Advanced Distribution Management System (ADMS)
• Possible commands to Intelligent Device Controllers
Interactions with other
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 Element Description
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.
Interactions with other
Primary Actors
• Remote Terminal Units (RTUs)
• Commissioning Engineers
Interactions with other
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 Element Description
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.
Interactions with other
Primary Actors
• The Advanced Distribution Management System (ADMS)
• 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
• Commissioning Engineers
Interactions with other
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 Element Description
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.
Interactions with other
Primary Actors
• Remote Terminal Units (RTUs)
• Commissioning Engineers
Interactions with other
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 the issue can be fixed via
DSR or other smart measureDSR or other
If periodic network
reconfiguration can
solve the constraints
Primary ConnectIf support from another primary
substation is required
Traditional
Reinforcement
If no lower cost solution is
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
Feedback loop – where the characteristics of the problem change
Concept for UC2: HV/LV Network Issue
If the issue can be fixed via
DSR or other smart measureDSR or other
If periodic network
reconfiguration can
solve the constraints
If support from another primary
substation is required
Traditional
Reinforcement
If no lower cost solution is
possible
TOOLBOX OF
POTENTIAL SOLUTIONS
Active Response 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
Feedback loop – where the characteristics of the problem change
Concept for UC3: Primary Substation Overload
If the issue can be fixed via
DSR or other smart measureDSR or other
Primary ConnectIf support from another primary
substation is required
Traditional
Reinforcement
If no lower cost solution is
possible
TOOLBOX OF
POTENTIAL SOLUTIONS
Active Response Solution
Main MenuUse Cases
132
Swinging load
group identifiedModel to assess
regime
economics
Operate
and
Monitor
solution
Feedback loop – where the characteristics of the problem change
Asses Issues
and identify
most cost
effective
solution
Pri A Pri B
Concept for UC4: Swinging Load Group
If the issue can be fixed via
DSR or other smart measureDSR or other
Traditional
Reinforcement
If no lower cost solution is
possible
TOOLBOX OF
POTENTIAL SOLUTIONS
Active Response 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
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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
Main MenuIT/OT Solution
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.
Main MenuIT/OT Solution
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.
Main MenuIT/OT Solution
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.
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149
Principal real-time components
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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.
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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.
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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
Interface between data types
Interface between data types
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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
Interface between data types
Interface between data types
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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
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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.
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IT/OT Requirements
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158
The requirements are categorised as follows:
How the IT/OT requirements have been presented
Main MenuIT/OT Solution
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
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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
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End of IT/OT Solution Section
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