Upload
others
View
1
Download
0
Embed Size (px)
Citation preview
Distributed Generation Customer Forum 30 June 2015
2011. UK Power Networks. All rights reserved
Time Agenda Subject Session type Presenter
09.30 Welcome & Introduction Main room Steve Halsey and Steve Bradley
09.40 The March Rush - delivery Main room Ian Cameron
10.00 The network • Capacity • Overcoming the challenges • Flexible DG
Main room Tim Moore & Matt White Luke Wainwright & Ben Marshall (NG) Sotiris Georgiopoulos
11.15 Tea & Coffee
11.30 Technical Commercial Delivering the service you want
Breakout sessions
Tim Moore & Matt White Luke Wainwright & Ben Marshall Jim Vasey, Steve Foster & Steve Carlow Steve Rogers & James Devriendt
13.15 Lunch
14.00 Incentive on Connections Engagement (ICE) Main room Steve Halsey
14.20 Wayleaves & Legals Main room Noel Jemma
14.45 DG mapping tool Main room Steve Halsey & Meghana Garg
15.00 Q&A close Mark Adolphus
2
2011. UK Power Networks. All rights reserved
Introductions Who’s here today from UK Power Networks?
Connections
Mark Adolphus Director of Connections
Steve Bradley Head of Major Connections
Steve Halsey DG Development Manager
Jim Vasey Major Connections Manager EPN
Steve Carlow Major Connections Manager SPN
Steve Foster Major Connections Manager SPN
Steve Rogers CiC Manager
Kellie Dillon DG Business Analyst
Keir Spiller Project Manager EPN
Julian Tidd Project Manager SPN
James Devriendt Connections Manager SPN
Paul Atkinson Lead Design Engineer SPN
Stuart Hall Project Delivery Manager CiC
Iain Dilley Key Account Manager
3
Asset Management
Robert Kemp Head of System Development
Kevin Burt Substation Standards Manager
Tim Moore Infrastructure Planner DG
Matt White Infrastructure Planner
Sotiris Georgiopoulos Roll-out Lead- flexible connections
Jose Barros Infrastructure Planning Engineer
Erasmia Tiniou Graduate Engineer
Noel Jemma Deputy Consents Manager LPN & SPN
Capital Programme
Ian Cameron Senior Project Manager EPN
Giles Lincoln Senior Project Manager SPN
Engaging with Customers and Stakeholders
Welcome Steve Halsey DG Development Manager
2011. UK Power Networks. All rights reserved
Safety and housekeeping
• Toilets - Gentleman and disabled to the right, Ladies to the left
• Mobile phones
• No planned fire alarms
• Please inform Kellie if you need to leave early
5
2011. UK Power Networks. All rights reserved
Emergency exits Smile 1, 2, 3 & 4, Ground Floor, Prospero House
There are no planned fire drills today. If the fire alarm is heard
please leave the building using the nearest fire exit.
Once outside turn left onto Avon Place and assemble on
Swan Street.
6
Scene setting Stephen Bradley Head of Major Connections
2011. UK Power Networks. All rights reserved
8
Our objectives for today…..…
• Review of the first six months of 2015
• To provide an opportunity to give feedback
• Shaping our plans for next six months and
beyond
8
2011. UK Power Networks. All rights reserved
Start doing/More of
Stop doing/Less of
Your feedback throughout the day
9
Name:
Name:
We will review your ideas and opinions and will provide feedback to you at the
next DG Customer Forum as You said/We did/We will do
2011. UK Power Networks. All rights reserved
Where are we? Your views on seven key areas…
10
Where are we?Topic area 1 2 3 4 5 6 7 8 9 10
1 Our Information Provision
2 The Application Process
3 Our approach to Charging
4 The Choice you have
5 Technical
6 Our Engagement with you
7 Overall level of Customer Service
For each topic area above please put a cross in the box below the number that best represents
Name
Company
Lowest --------------------------------------------- Highest
where we are today
• Record scores on the score-sheet
• Hand-in before lunch
Review of 2015 & Connections landscape! Steve Halsey DG Development Manager
Introduction and scene setting
Steve Bradley Head of Major Connections
12
A busy six months!
• Start of new Regulatory period
• Numerous Ofgem consultations
• Incentive on Connections Engagement (ICE) plans
have been published
• Election – all change?
• Significant new renewable capacity added to our
network
• Ofgem workshop – network constraints
12
“Earlier end to subsidies for new UK
onshore wind farms”
2011. UK Power Networks. All rights reserved
>G83 - DG Enquiries
13
Vo
lum
es
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
2010 2011 2012 2013 2014 2015 actual YTD 2015 projected
14
• Acceptances 2,100MW
• Connected 7,975MW
• Half since formation of UK
Power Networks
Large Projects 1MW
2011. UK Power Networks. All rights reserved
7.6
7.7
7.8
7.9
8
8.1
8.2
8.3
8.4
8.5
8.6
8.7
2013 2014 2015 YTD
Average satisfaction score 2013-15 YTD
DG Customer Satisfaction score
2013, 2014 & 2015 YTD
15
Average score increased from 7.97 in 2013 to 8.46 in 2014 to 8.58 in 2015 YTD
2011. UK Power Networks. All rights reserved
Date Event Location
10 September DG Customer Forum London
29 September Competition in Connections workshop London
15 October Connections customer forum London
22 October Connections customer forum South East
27 October Connections customer forum East Anglia
3 November Highway Assets forum TBC
Stakeholder Engagement 2015
16
IMPORTANT – OUR NEXT DG CUSTOMER FORUM WILL BE HELD AT A NEW LOCATION IN HOLBORN
2011. UK Power Networks. All rights reserved
The Voice of the Networks – DG Fora 2015
17
2011. UK Power Networks. All rights reserved
The Future – what’s next?
18
• More Community Energy projects
• Integrating National Grid plans
• Mixed technology sites
• Storage
• Managing challenge of network constraints
18
Delivery update Ian Cameron Senior Project Manager – Eastern region
2011. UK Power Networks. All rights reserved
20
The end-of-March rush
• 4 - 132kV connections, three within six months of payment
• 36 - 33kV connections
• When is the next deadline/rush?
• >500MW connected
in March
20
2011. UK Power Networks. All rights reserved 21
Used ABB (Plug and Switch System) PASS
units for the first time in UK Power Networks.
Melbourne Grid
2011. UK Power Networks. All rights reserved
In Delivery DG Volumes (>1MW)
22
Last forum - Today Planned for connection
to end of 2015
Planned for connection
thereafter
Total Number of
Connections 54 51 76
Total Capacity of
Connections in MW 677 658 1453
Number of 11kV
Connections 9 5 10
Capacity of 11kV
Connections in MW 31 26 34.80
Number of 33kV
Connections 35 45 51
Capacity of 33kV
Connections in MW 431 561 723
Number of 132kV
Connections 5 2 15
Capacity of 132kV
Connections in MW 215 71 695
2011. UK Power Networks. All rights reserved
Looking ahead
• Post March 2015
–Seen a significant shift toward sub 5MW schemes
–More schemes considering shared community energy
–Are the days of >10MW schemes (CfD’s) finished?
• Will we see more cancellations of other larger schemes
or reductions to 5MW?
• Rooftops?
• London?
• What went well – what could have been better?
23
Distribution and transmission networks Tim Moore & Matt White Infrastructure Planning Engineers
Luke Wainwright & Ben Marshall National Grid
Sotiris Georgiopoulos Flexible DG Lead
2011. UK Power Networks. All rights reserved
25
• Impact of DG
• Overview of transmission network
• Transmission network in South East
• Managing capacity
• Flexible DG
The Network
25
26 26
DG Connected to our networks
Type/Area EPN MW LPN MW SPN MW
G59* 5,966 493 1,378
G83 to 2012 60 4 26
G83 2013 8 0.4 2.3
G83 2014 12 0.75 3.9
G83 2015* 15.2 1.11 4.89
TOTAL 6,061.2 499.26 1,415.09
7.975GW DG Connected
*To end of May 2015
2011. UK Power Networks. All rights reserved
Statement of Works GSP Sites EPN
27
2011. UK Power Networks. All rights reserved
EPN Heat Map
28 Eastern Power Networks capacity map
2011. UK Power Networks. All rights reserved
Statement of Works GSP Sites SPN
29
2011. UK Power Networks. All rights reserved
SPN Heat Map
30 South Eastern Power Networks capacity map
2011. UK Power Networks. All rights reserved
Network Constraints
• Transformers – reverse power capabilities of individual
units
• Switchgear – fault levels (synch DG), thermal
• Circuits – complexity, thermal ratings, length/impedance
• Voltage Control – voltage step change, voltage rise
• Protection – effects of DG on directional protection
• Network configuration i.e. coupled, interconnected
• Transmission Constraints (National Grid presentation)
• Reactive Power exchange – High Volts, EDCC¹
¹EDCC – European Demand Connection Code
31
2011. UK Power Networks. All rights reserved
Technical - Circuit Complexity
• The permitted number of connections That can be made to the EHV
networks are governed by, EREC P18 for 132kV and UKPN standard EDS
08-0145 for 33kV schemes. Essentially the rules for both voltage levels are
the same.
• These are:- UK Power Networks shall apply no more than seven points of
isolation both for underground and overhead teed circuits and shall not be
located on more than four different sites.
• The reason for these conditions are to allow sufficient network flexibility in
the event of a fault or a planned outage and also to simplify operational
requirements.
• Complex networks may have a considerable number of credible running
conditions and the protection schemes and settings become complex. This
may lead to an increased risk of mal-operation and human error.
32
2011. UK Power Networks. All rights reserved
Circuit Complexity
• Traditionally this hasn’t normally been a problem because connection points
have been designed around providing maximum capacity in an area, i.e.
you wouldn’t normally expect to have a large number of 132kV substations
all within close geographical area.
• However large numbers of generation connections in recent years have
pushed circuit complexity to the limits in some areas. Now smaller 5 MW PV
connections are likely to put further pressure on the network.
• For example A 33kV Overhead line may have capacity for 20 MW of
generation however if there are already 3 ends and we offer a 4th end to a
5MW PV that effectively sterilises that network for the remaining capacity.
• There are no FDG (Smart grid solutions to this issue)
33
2011. UK Power Networks. All rights reserved
Circuit Complexity Examples
34
Grid Substation
S/S A
G
G
Example 1
S/S A
S/S B
S/S B
S/S C
Grid Substation
Example 2
2011. UK Power Networks. All rights reserved
High Volts
• National decline in minimum demand (Q/P ratio) – less
inductive loads – trends to more capacitive network
• Impact at lower voltages amplified at GSP’s¹ (1:1.5)
• Issue with high volts on the NETS² during periods of
minimum demand – quality of supply, Q compensation
• DG reduces demand on the network = increase in
voltage gain on lightly loaded EHV circuits
• EHV cables significant effect on Q
–EHV DG introduces additional EHV cable circuits
¹GSP – Grid Supply Point
²NETS – National Electricity Transmission System
35
2011. UK Power Networks. All rights reserved
Power Factor (PF)
• No. of Connection Agreements indicating a leading
power factor for active power export i.e. absorb VAR’s
neutral effect on reactive power exchange
• Network conditions/connections drive voltage profile
• Ensure voltage maintained within statutory limits to
ensure quality/continuity of supply to all customers
• Ability to operate range of 0.95 lead to 0.95 lag
• Grid Code requirement
• Target p.f. nominally unity as per NTC¹
• Where connections identified as having impact – specific
p.f. and/or range
¹NTC – National Terms of Connection
36
2011. UK Power Networks. All rights reserved
What we’re doing? Options for consideration
• Some of the potential solutions currently being
modelled/assessed:
–Reactive compensation
–Target Volts
–Tap staggering
–Circuit switching
–Power factor
37
Place your chosen
image here. The four
corners must just
cover the arrow tips.
For covers, the three
pictures should be the
same size and in a
straight line.
UK Power Networks DG Customer Forum
National Grid
Luke Wainwright & Ben Marshall 30th June 2015
Agenda
National Grid’s Role
Overview of the Challenge
Data
South East
East Anglia
What’s Next?
39
Overview –
GB Electricity Operations (TO and SO)
Sco
t
Po
wer
Nati
on
al
Gri
d
Na
tion
al G
rid
Sco
t
Hyd
ro
System Operator Transmission Owner
System Design
Project Management
Engineering and
Maintenance
System Planning
System Operation
Market Facilitation
Energy Trading
Overview- The Pace of Change-
Growth in Solar Generation
Heat Map of GB Solar Capacity
42
Overview - The national system challenge
Wider area of the network experiencing
high voltage challenges
Declining Q/P Ratio
Due to high Mvar utilization, some
generators have withdrawn reactive
range at times
Not just a GB Issue – Other European
TSOs have achieved success in the
management of EG resources.
Minimum Demands (Average of lowest three)
21895 22186 21901
21220
19732
20535
19102
1934319487
2195
7599 7659
66576193
5062 4624
30613583
0
5000
10000
15000
20000
25000
2005 2006 2007 2008 2009 2010 2011 2012 2013 (?)
0.1
0.15
0.2
0.25
0.3
0.35
Average Min MW Average Min MVAR Q/P Ratio
Data - Wider Statement of Works
Process - Straw Man
43
DNO
Submits aggregated
forecast data
(Week 24?)
NG/DNO
System studies
and liaison
(JTPM?)
NG
Define current system capacity.
Define actions to increase capacity.
NG
Is application within
unallocated study
limits
DNO
Make SoW
application
(aggregated)
DNO/DG
Discuss likely
impact with DG
DNO
Assess Transmission
impact against
background studies
DG
Connection
application to
DNO
DNO
Offer to DG
NG
Offer to DNO
NG
Full study to
current SoW
process
DG
Accept/Reject Offer
N
Y
Data - GC0042- Requirements
for new generation
It is important that data is provided in
accordance with the Grid Code GC0042. -
this avoids uncertainty and invisibility of
demand impacts
Applies to projects with a registered capacity
of 1 MW or above.
Additional data to be provided include:
A reference unique to each Network
Operator
Fuel Type (Pre 2015 / Post 2015)
Registered capacity
Connected node specified in the most up-
to-date SLD
Location if wind or PV (Latitude,
Longitude, Grid Ref.)
Loss of Mains Protection: Type & Setting
PF Control Mode
Voltage Control: set-point & reactive
range
Power Factor Control: Target
44
Place your chosen
image here. The four
corners must just
cover the arrow tips.
For covers, the three
pictures should be the
same size and in a
straight line.
The South East System Challenge
46
South East - Transmission System
IFA2
ElecLink
Nemo
IFA2
ElecLink
Nemo
South East loop, is an Existing 270km long 400kV double circuit route between
Kemsley (North Kent) and Lovedean ( near Southampton), interspersed with existing
substations at Bolney, Ninfield, Sellindge, Canterbury and Cleve Hill.
Network includes some 2.3GW of peak domestic supply, and some 2.5GW of large
generation (0.7GW of which is embedded), with some further 0.6GW of small &
medium embedded generation plus an existing 2 x 1GW Bipole CSC-type HVDC link
between UK and France
South East - A system with
unprecedented challenges…
47
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
0% 20% 40% 60% 80% 100%
NS
G/D
em
an
d
Percentage of Time
2014/15
2019/20
2024/25
2029/30
2034/35
South east-
Far higher Power Electronic
content than anywhere else
in UK
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100%
NS
G/D
em
an
d
Percentage of Time
2014/15
2019/20
2024/25
2029/30
2034/35
Scotland
48
South East – A system with low strength
Current minimum fault level under maintenance conditions at Sellindge is c. 6.9kA,
otherwise approximately c.11.5kA- compare this to Kemsley, which is 3 times as strong.
Only one major synchronous source in area at Dungeness.
Leads to high degree of vulnerability as voltage disturbance is seen over a wide system area-
as evidenced in real network behaviour illustrated in voltage and frequency traces above.
Voltage DipsSellindge 400kV
Voltage drops to:
Fault Location
Less than 20%
Less than 50%
Less than 65%
Less than 75%
Less than 85%
Voltage drops to:
Fault Location
Less than 20%
Less than 50%
Less than 65%
Less than 75%
Less than 85%
Current Data
(Summer Min)
Scotland
Current Data
(Summer Min)
ScotlandScotland
2023/2024 Data
(Summer Min)
Scotland
2023/2024 Data
(Summer Min)
ScotlandScotland
South East - What this means for
Embedded Generation?
Power factor specification (up to 0.95pf
lead) containing steady state
Dynamic 0.95pf lead-lag Reactive range
capability avoiding Overvoltage & future
Voltage instability, ROCOF Collapse
Post-fault intertripping/ de-loading
aligned with transmission system
approach
Limitation on firm connection offers until
2026 (reinforcements)
Where necessary, for specific conditions,
as necessary and dependant on the
above, pre-fault restriction….
49
420kV
415kV
410kV
405kV
400kV
395kV
390kV
385kV
380kV
South East - How we
currently handle these challenges...
Grid
Code
SQSS
New Embedded Generation impacts our management of these areas –
and will need to be subject to extensions of these same arrangements
Voltage
Regulation
Transient
Over-Voltage
Interconnector
Stability
Nuclear power Station
Stability impacts
Voltage
Stability
Thermal
Power Quality
New shunt compensation, innovative
interconnector control and operation, co-
ordination with DNO
More concentration of Innovative Dynamic
Compensation than elsewhere in GB
Quad Boosters, Intertripping and pre-fault
restrictions
Filters, Phase Balancers, restrictions
Specialist analysis Co-ordination and
assessment across Industry and Suppliers
Pre-fault restrictions, control systems
design and specialist co-ordination.
Unique specification of compensation on
GB system, specialist control system and
design approaches
Place your chosen
image here. The four
corners must just
cover the arrow tips.
For covers, the three
pictures should be the
same size and in a
straight line.
The East Anglia System Challenge
52
East Anglia - The Transmission Network
Main boundary considered for reinforcement is East
Coast 5 (EC5)
Against angular stability limits roughly 2 GW
Capacity for connections at Bramford, Norwich and
Sizewell, dependent on characteristics and
locations of connections.
This level is already exceeded in connection
capacity in the area- a new route; Bramford-
Twinstead is under consideration.
Existing widespread use of intertripping for thermal
and stability reasons
Existing intertripping for Negative Phase Sequence
(NPS) based on local system strength and flow
issues which again a new route would address.
Transient Over-Voltage suppression already in
place with wind-farms connected in the area
Again, Nuclear Generation connection in the vicinity
requiring strong liaison
Embedded generation once again will need to be
included in existing and extensions of this management
approach as required
62
0
62
2
62
6
62
4
34
AB
CD
A B
1
2
646603
611
2
1
654
65G
602
615
A616612
600A
B
601
653
1
A
642
683
68B638
F685
1 2
B
A64F643
6442641
658657
659
494
655
12
W ALPOLE
NORW ICH
MAIN
1 21 2
403
420
41E
488
442
1
492
421
2 1
418
415
443
412
487
486
F608
F609
21
B
605
604
617
618
A
B
1 2
635
636A
BRAMFORD
SUTTON
BRIDGE
SIZEW ELL
RAYLEIGH
MAIN
CORYTON
SOUTHTILBURY
BRAINTREE
HIGH
MARNHAM
PELHAM
EATON
SOCON
RYE HOUSE
W ARLEY
RATCLIFFE
ON SOAR
SUNDON
ELSTREE
GRENDON
ENDERBY
1
2
1 2
12
2
1
1
2
1 2
669
2 4 362
5
62
3
STAYTHORPE
161
9
68A
F6
13
F6
14
F6
17
F6
18
W ALTHAM
CROSS
608
489
SPALDING
NORTH
W YMONDLEY
MAIN
408
AQ404
A Q421
R607
A607
39
1
391
62
1
1 2
B
21
1
2
65H
645
B
39D
W EST
BURTON
S62BB
685
686
S62AA
39F
R430
COTTAM
2
493
1
TILBURY
787F686
637
2
413
1
2
788
3 650
STOKE
BARDOLPH41F
4 65B
1 2
2
1
BURW ELL
MAIN
BICKER
FEN
Area
Considered
in Strategy
EC5
53
East Anglia – An area of significant
Generation development
High volume of committed projects and power
flow volatility in this area.
Some new rail connection activity on demand
side also.
Major new reinforcements planned
Transmission connection position
Embedded Onshore wind and Solar growth…?
East Anglia – System issues System strength- a potential challenge by 2035…
Power Quality (NPS, TOV) and Stability issues more significant
today..
54 .15 .4 .65 .9 1.15 1.4 1.65 1.9
Peak Voltage p.u.
0
50
100
150
200
250
300
350
400
450
500
550
Frequency ( /3993)
East Anglia - What this means for
Embedded Generation?
Power factor specification in order to
containing steady state voltage.
Dynamic Reactive capability supporting
Angular and voltage stability of generation
ahead of new route.
Post-fault intertripping/ de-loading
Where necessary, for specific conditions, as
necessary and dependant on the above, pre-
fault restriction.
Severity of measures dependent on rate of
connections in the area and their design…
55
420kV
415kV
410kV
405kV
400kV
395kV
390kV
385kV
380kV
What Next?
Close engagement with the DNO’s
Working towards limits at GSP’s and across collections
of GSPs
Closer engagement with the developer community
Industry wide solutions to an industry wide challenge
Innovation
Regulatory and Governmental Involvement
(Ofgem/DECC)
56
Place your chosen
image here. The four
corners must just
cover the arrow tips.
For covers, the three
pictures should be the
same size and in a
straight line.
Appendices
3.4 GW
4.8 GW
5.3 GW
7.9 GW
Limiting challenge: ToV
To resolve:
- Dynamic range -0.95 pf lead needs to be available
Challenge: increased ToV Voltage Collapse, stability of system
To resolve:
-dynamic 0.95pf lead-lag capability on connecting plant
- Additional network dynamic compensation proposed 2019
Challenge: further ToV at Sellinge and Voltage Collapse at
Sellinge, system stability
- By this point some 1700Mvar additional faster compensation,
or more significant changes to network topology.
- Measures adopted below affect incidence
Dynamic NSG challenges for South East
NSG
Current commissioned
NSG = 3350MW
- T-NSG 300MW
- HVDC 2000MW
- E-NSG 900MW
- M-NSG 150MW
Challenge: ToV . Stability and voltage collapse
-To resolve: total of 5100MVAR support or alternate network
changes
Thermal limit without reinforcement
4.0003.0002.0001.0000.000-1.000 [s]
-0.185
-0.547
-0.909
-1.271
-1.632
-1.994
DNGB8\DUNG_85: s:phi
MAWO8\MAWO_8S: Rotor Angle in rad
DNGB8\DUNG_86: Rotor Angle in rad
4.0003.0002.0001.0000.000-1.000 [s]
1.558
1.297
1.037
0.776
0.516
0.255
CANT4\CANT4 MC4: Voltage, Magnitude in p.u.
BOLN4\BOLN4 R2: Voltage, Magnitude in p.u.
DUNG4\DUNG4 M3: Voltage, Magnitude in p.u.
LOVE4\LOVE4 M2: Voltage, Magnitude in p.u.
NINF4\NINF4 M2: Voltage, Magnitude in p.u.
SELL4\SELL4 M1: Voltage, Magnitude in p.u.
4.0003.0002.0001.0000.000-1.000 [s]
2.0E+3
1.0E+3
0.0E+0
-1.0E+3
-2.0E+3
-3.0E+3
DNGB8\DUNG_85: m:Q:bus1
MAWO8\MAWO_8S: Reactive Pow er in Mvar
DNGB8\DUNG_86: Reactive Pow er in Mvar
4.0003.0002.0001.0000.000-1.000 [s]
50.19
50.08
49.98
49.88
49.77
49.67
ELST2\ELST2 M2: Electrical Frequency in Hz
Results 3
Date: 5/21/2015
Annex: /2
DIgS
ILE
NT
Data - Forecasting difficulties
& control challenges
FES 2014
Visible = 17%
Current % Of Embedded
Generation by size ( Dec 2014)
Invisible Embedded
Generation
Scottish Hydro-Electric
Transmission Ltd
National Grid Electricity
Transmission
TO - Transmission Owners
(SHETL, SPT, NGET, Offshore)
SO - System Operator
(NGET – GB Wide)
System operation / balancing
System planning / user interface
Market facilitation
High voltage electricity assets
Capital investment
Maintenance
Scottish Power
Transmission
Facilitate competition in generation & supply)
Ensure network allows electricity demand to be met-
Economically, co-ordinated, secure
Signal to industry Future Planning challenges
Role of GBSO & Transmission Networks
Affordability
Security of
Supply Sustainability
How Changes At Distribution level impact
Transmission system
Active Distributed Generation effects:-
Wider transmission power flow change
Balancing system frequency
More potential range and uncertainty surrounding system conditions
to be planned for security and quality of supply.
Data exchange via Grid Code and Statements of
Works Is Essential to manage this..
61
Protection
schemes
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 24:00
15
20
25
30
35
40
45
50
55
Typical Summer Day
Minimum Summer Day
Typical Winter Day
Maximum Winter Day
GW
00:00 02:00 04:00 06:00 08:00 10:00 12:00 14:00 16:00 18:00 20:00 22:00 24:00
15
20
25
30
35
40
45
50
55
Typical Summer Day
Minimum Summer Day
Typical Winter Day
Maximum Winter Day
GW
Future Distribution Systems
Signalling Into The Future..
Annual Updated, Industry Consulted:- driving Investment, Innovation & Policy
62
System Operability
Framework
Electricity Ten Year
Statement
63
Background- System Characteristics
- steady state voltage performance
Across the GB network, the levels of
reactive demand at GSP have been
falling faster than the active power levels
at times of overnight minimum load
leading to voltage containment
challenges and challenges in managing
interconnector reactive exchanges.
Within the South East transmission
network, the load follows the national
average of between 25-30% of the peak
demand MW level and is broadly
comparable with the national trend.
420kV
415kV
410kV
405kV
400kV
395kV
390kV
385kV
380kV
Minimum Demands (Average of lowest three)
21895 22186 21901
21220
19732
19102
1934319487
7599 7659
66576193
5062 4624
30613583
0
5000
10000
15000
20000
25000
2005 2006 2007 2008 2009 2010 2011 2012
0.15
0.17
0.19
0.21
0.23
0.25
0.27
0.29
0.31
0.33
0.35
Average Min MW Average Min MVAR Q/P Ratio
64
Background- System Characteristics- Thermal
Within the South East transmission
network, network capacity is
insufficient to permit full output under
maintenance conditions across the
area following a further double circuit
fault.
Conditions drive deloading of a 1GW
HVDC bipole at Sellindge and/ or
deloading within 10s of Cleve Hill
capacity by 320MW/ 640MW or
Thanet by 315MW.
May also be used to protect network
during interconnector export
conditions.
QBs at Kemsley used pre-fault to
reduce post fault flow bias into/ from
Kemsley for fault conditions at the
area- as such, they would nominally
be in service on Kemsley-Canterbury/
Clevehill circuits.
65
Background- System characteristics-
Thermal position & constraint summary
Existing network (generation installed) each circuit on the above loop is reconductored with
(between Dungeness and Kemsley) with GAP conductor on L2 tower construction and between
Sellindge and Lovedean and Sellindge with 3x 700mmsq AAAC conductor- the highest capacity
available. Residual two circuits loaded between 60 and 98% post fault dependent on year round
rating
Dungeness C
(1.65GW)
(2019) Hastings(0.
67GW) (2016)
(60%)Cant + (40%) Sellindge group= 0.54GVA (now), 0.55GVA (2018)
Bolney group= 0.89GVA
(now), 1.06GVA (2018)
Ninfield group= 0.46GVA
(now), 0.49GVA (2018)
Kemsley group= 0.18GVA (now), 0.20GVA (2018)
Thermal limit= 5500MVA (summer N-D); 6200MVA (winter N-D); 2750MVA
summer N-3)
Voltage & stability limit = 5600MVA (import voltage), 4714MVA (import stability-
includes 1 dung unit)
66
East Anglia- EPN Distribution Network
• Interconnected- Parallel to
transmission system
• Actively managed between us
• Growth across area..
67
Background- System Characteristics-
System strength
Current minimum fault level under maintenance conditions at
Sellindge is c. 6.9kA, otherwise approximately c.11.5kA- compare
this to Kemsley, which on the edge of the study area and closer to
Thames Estuary where minimum fault level of 20kA exists
Only one major synchronous source in area at Dungeness.
Leads to high degree of vulnerability as voltage disturbance is
seen over a wide system area- as evidenced in real network
behaviour illustrated in voltage and frequency traces above.
Voltage DipsSellindge 400kV
Voltage drops to:
Fault Location
Less than 20%
Less than 50%
Less than 65%
Less than 75%
Less than 85%
Voltage drops to:
Fault Location
Less than 20%
Less than 50%
Less than 65%
Less than 75%
Less than 85%
Current Data
(Summer Min)
Scotland
Current Data
(Summer Min)
ScotlandScotland
2023/2024 Data
(Summer Min)
Scotland
2023/2024 Data
(Summer Min)
ScotlandScotland
Voltage recovery @IFA1- Bolney busbar fault 02/04/13
300000
320000
340000
360000
380000
400000
420000
440000
53
:15
.0
53
:15
.2
53
:15
.4
53
:15
.7
53
:15
.9
53
:16
.1
53
:16
.3
53
:16
.5
53
:16
.8
CANT 1 VoltsMagnitude
Frequency recovery -bolney busbar fault- 02/04/13
48.8
49
49.2
49.4
49.6
49.8
50
50.2
53
:15
.0
53
:15
.2
53
:15
.4
53
:15
.7
53
:15
.9
53
:16
.1
53
:16
.3
68
What is UK Power Networks doing?
• Investigating short/medium term options:
– Revisiting system target volts
– Network reconfiguration
– Moving demand/generation groups
– Active network management
– Management of Capacity
• Reinforcement – long term, significant timescales,
costs, etc.
2011. UK Power Networks. All rights reserved
Management of Capacity
• UK Power Networks published it
Management of Capacity document in
December 2014. The Document amongst
other things lists the order in which released
capacity will be available starting with
customers who are in band E and working
backwards.
69
• To clarify, the amount of capacity that
will be offered to customers in this
band (and bands working backwards)
will be based on a figure up to the
maximum requested in the original
application. Where this additional
capacity is less than the total released
capacity then any further capacity
would be offered to the next customer
in the queue (based on application
date order).
2011. UK Power Networks. All rights reserved
Management of Capacity
• If for whatever reason a scheme does not progress, then there is no
assurance that all of that particular scheme’s capacity will become available
for use by others. There are a number of reasons why this may not be
possible.
– Continuing growth in small scale G83 DG during the regulatory period.
– Constraints within the UK Power Networks or National Grid networks that
were not apparent when the original provisional price offers were made.
– Circuit complexity requirements (mentioned earlier) may limit the number
of connections that can be made in an area.
– Location specific
71
Response to Stakeholder consultation
2011. UK Power Networks. All rights reserved
Management of Capacity
• Generation connection under EREC G83 is done on a fit and inform basis.
UK Power networks is only advised of this generation once it has been
connected.
• A consistent 1000-1200 G83 notifications per month are received across UK
Power Networks area.
• Assuming an average capacity of 3 KW, this equates to around 40 MW /
year.
• If this continuous at the same rate then we will have potentially another
320MW of additional generation at the end of the current regulatory period.
• In areas that are already constrained this may produce significant
challenges to the operation of the network.
72
2011. UK Power Networks. All rights reserved
Management of Capacity
• Some customers are requesting additional generation technologies at
existing sites. e.g. STOR* generation and energy storage devices. It is
intended that these will operate within existing export limits, but will alter the
output profile of the site.
• We would consider this to be a significant change to the operation of the
site and it would therefore be subject to a new application for the additional
generating units.
• Additional studies would be required to determine the impact of the new
export profiles to determine if this has a detrimental effect on the existing
network.
• In particular where the area has been declared an FDG area, this may
impact on constraint levels for existing customers, and may have to be
restricted at certain times.
*STOR – Short Term Operating Reserve
73
2011. UK Power Networks. All rights reserved
What we’re doing – the way forward
• On-going dialogue
• Continued review of slow moving projects
• Queue management
• Clarity around offers
• National Grid are establishing a Statement
of Works working group
• Flexible or unconstrained offers
74
Flexible Distributed Generation round 2 Sotiris Georgiopoulos
2014. UK Power Networks. All rights reserved
Building flexibility for DG connections
• Traditional methods ( inter-tripping, use of N capacity),
over 1.1GW of “N-1 constrained” generation within EPN
and SPN networks
• Flexible connections using active network management
(FPP, FDG)
• Flexible connections using advanced active network
management systems and commercial arrangements
(FDG and KASM)
76
2014. UK Power Networks. All rights reserved
Operational deployments
March
Grid
zone
Norwich
zone
Grid Supply
Point
Walpole Norwich Main
Voltage levels 33kV and
below
132kV and
below
Contracted
DG
30MW 130MW
Operational
DG
25MW 20MW 77
March Grid zone
Norwich zone
Benefiting 30 projects
2014. UK Power Networks. All rights reserved
Operational Deployment – learning
78
Nov 13 – Nov 14
Functional testing using
simulation
Nov 14 – Apr 15
Eight generators are commissioned
Feb 15 – May 15
Storm period
May 15 – Dec 15
Stabilisation and
enhancement
More DG connects
Monitoring and Improvement
Operational trial (soak testing)
Performance
We have resolved issues caused by configuration, accuracy / speed of/resiliency
of measurements, set-point interaction between generators and DNO.
Working with customers
Full handover to operations
Progressing e-mail notification system, exploring webpages for incident
communications
Understanding requirements for CHP
2014. UK Power Networks. All rights reserved
2014 2016
Norwich (EPN,
November 2014)
Peterborough
March Extension
(EPN, October
2015)
Fleet Hall (EPN,
April 2016)
Flexible DG connections rollout - areas
• Following feedback from National Grid, we have prioritised the Sittingbourne area
while further work is being carried out on the South Coast GSPs
79
2015
Peterborough-
March (EPN,
March 2013)
Lewes Eastbourne
(SPN,TBC)
Sittingbourne /
Kemsley (SPN,
February, 2016)
2014. UK Power Networks. All rights reserved
Flexible Distributed Generation zone -
Kemsley
Grid and Primary sites (FDG Kemsley)
1) Sheerness Grid 132/33kV
• Sheerness 33/6.6kV
• Queenborough 33/6.6kV
• Eastchurch Prison T2 33/6.6kV
• Minster T2 33/6.6kV
2) Sittingbourne Grid 132/33kV
• Sittingbourne West 33/11
• Faversham 33/11kV
• Rainham 33/11kV
• Sittingbourne Town 33/11kV
• Eastchurch Prison T1 33/6.6kV
• Minster T1 33/6.6kV
• Leysdown 33/6.6kV
3) Grovehurst Grid 132/33kV
• Grovehurst Local 33/11
Source: Long Term Development Statement
2014. UK Power Networks. All rights reserved 81
Expression of interest (non-
binding) for currently
constrained area initiating
01 July 2015
Single Line Diagram Kemsley GSP
2014. UK Power Networks. All rights reserved
Install Contingency Analysis (CA) software Model the East Kent (SPN)
Establish a link between the UK Power Networks and the National Grid
control rooms To enable real-time data exchange
1) Reliability management (Control)
Develop and integrate the forecasting modules in the CA software For DG and demand in the network
2) Outage Management
3) Network Capacity Management
• Pro-actively Identify and mitigate harmful
contingencies in Real-time
• Reduce outage constraints on generators
• Allow new generators to join the network
Bu
ild
T
rial / U
se C
ases
Kent Active System Management (2015 -17)
2014. UK Power Networks. All rights reserved
• Stabilising the operational customers has been a priority
• Committed to delivering benefit in SPN, focusing now in
the area of Kemsley
• The South East requires further development of existing
technical and commercial solutions (V2)
• Focused on delivering a scalable model for the long-term
83
Summary
2011. UK Power Networks. All rights reserved
Breakout rooms
84
Tables 1&2
Tables 3 & 4
Return to same room
Smile 1
R/H/S return to same
seats
L/H/S Go to Smile 4
Folding doors will be closed during the break
Break Please reconvene at 11:30am
Technical, Commercial & Delivering the
service you want breakout sessions
2011. UK Power Networks. All rights reserved
• Technical
Tim Moore, Matt White & Kevin Burt and National Grid
• Commercial
Steve Carlow, Steve Foster & Jim Vasey
• Delivering the service you want
Steve Rogers & James Devriendt
PRESENTERS WILL ROTATE
87
Breakout sessions
2011. UK Power Networks. All rights reserved
Technical Break-Out Session
• Network Constraints
»Circuit Complexity
»High Volts
• National Grid
»Challenges
• Innovation
• What's next? Storage? New tech?
88
2011. UK Power Networks. All rights reserved
Commercial Issues
• Community Schemes
– What’s the preferred approached to enquiry i.e. separate enquiries
or same enquiry.
• Considerations
– Interactivity
– Metering - how?
– Connection agreements?
• Slow moving projects
– At what stage should we consider absolute termination?
• Stage Payments
– Are they set at the correct levels?
• What other commercial issues should we be
considering?
89
2011. UK Power Networks. All rights reserved
Permitted arrangement
90
10MW capacity site
1 MPAN 1 Connection
agreement 1 lead
organisation
5MW Commercial 5MW Community Energy
M
1 Connection agreement 1 lead organisation standard MPAN
1 pseudo MPAN with agreement between Commercial & Community
M
1 Connection agreement with lead organisation 2 MPAN
Commercial grants rights to Community to trade on 2nd MPAN
THIS SLIDE COMPRISES A BUILD OVER 3 THREE SLIDES –
THESE ARE SHOWN ON THE SUBSEQUENT SLIDES
2011. UK Power Networks. All rights reserved 91
2011. UK Power Networks. All rights reserved 92
2011. UK Power Networks. All rights reserved 93
2011. UK Power Networks. All rights reserved
Commercial Issues
• Slow moving projects
– At what stage should we consider absolute termination?
• Stage Payments
– Are they set at the correct levels?
• What other commercial issues should we be
considering?
94
2011. UK Power Networks. All rights reserved
Delivering the service you want –
Key customer touch-points
• Providing guidance to our stakeholders of our strategic intentions
– Involvement in policy evolution
– Provision of information (Heat maps)
– Account management
• Pre-application support
– DG surgeries
– Other mechanisms
• Engagement prior to quotation
• Communication during construction
95
2011. UK Power Networks. All rights reserved
Lunch?
96
Where are we?Topic area 1 2 3 4 5 6 7 8 9 10
1 Our Information Provision
2 The Application Process
3 Our approach to Charging
4 The Choice you have
5 Technical
6 Our Engagement with you
7 Overall level of Customer Service
For each topic area above please put a cross in the box below the number that best represents
Name
Company
Lowest --------------------------------------------- Highest
where we are today
Please reconvene at 2:00pm in the main room
Please hand your completed feedback form to Kellie
Incentive on Connections Engagement 2015/16 Steve Halsey
2011. UK Power Networks. All rights reserved
ICE plan
• Single plan covering all
segments
• Key DG activities are
–DG mapping tool
–Roll-out of Flexible
DG connections
–Community energy
focus
2011. UK Power Networks. All rights reserved
DG Service Improvement
Plan 2015/16
• Format unchanged
• 35 actions Customer led/driven
• Same 7 headline areas
– Customer Service
– Application process
– Information provision
– Technical
– Charging
– Choice
– Feedback
Headline
activity
Improvement
activityRef no
Sub ref
noWe Will… Target date Measure of success
Monitor customer
satisfaction1.1
Monitor and publish the customer satisfaction scores associated with the DG
connections activities of UK Power Networks. Mar-16 Average satisfaction score
Improved
turnaround
timescales for
formal quotations
1.2Reduce our quotation turnaround timescales by at least 5% on 2014/15
performance.Mar-16
5% improvement on 2014/15
quotation timescales
Best practice
development1.3
Ensure stakeholder views/feedback are used to develop appropriate initiatives
and share with DG-DNO Steering Group.Sep-15
Feedback captured, recorded,
reviewed and responded to
Customer portal 1.4Develop a customer access portal to allow customers to "self-serve" as part of
the wider UK Power Networks Business Transformation Project.Sep-15 Portal live and operational
Account
Management1.5
Provide an Account Management service to DG customers with multiple
schemes.Jun-15
Number of new DG customers
signed up to Account Managed
service
Customer touch
points1.6
Review key customer touch points to ensure customers receive a best in class
experience.Jun-15
Publish and share findings at
customer workshops
Provision of
Connection
Agreements
1.7Introduce process to support earlier completion of Connection Agreements
during the application and design stage of schemes.Jun-15
% of Connections Agreements
issued in advance of physical
connection completion
Stakeholder
Engagement1.8 Hold 3 DG Customer Forums (ex CEWs) per year. 3 per year DG Forums held
Optioneering 2.1Promote 1-2-1 discussions with customers to explore optimum availability of
capacity.Sep-15
Fewer multiple applications for
single sites
Surgeries 2.2
Improve visibility of surgeries and continue to offer surgeries as a key part of the
application/enquiry process. To discuss project viability ahead of a formal
application with all customers who request an appointment.
Ongoing
Surgery dates published -
connections.gateway@ukpowerne
tworks.co.uk to promote
Community Energy 2.3Develop, consult on and publish a Community Energy strategy to support the
development of Community Energy schemes.Sep-15 Publication of strategy document
Contracted
Connections
Register
3.1 Publish the 'Contracted DG Connections Register' online. Jun-15Contracted DG Connections
Register published
Capacity
management3.2
Proactively engage with customers where we believe a project is slow moving.
Projects that have been accepted to be reviewed with the customer every 3
months.
Ongoing
Capacity from slow moving
projects released in line with our
Management of Capacity
document
GIS maps (DG
Mapping Tool)3.3
Develop our DG Mapping Tool to provide visibility of network capacity by
including 'Heat Map' functionality and grid and primary substation capacities in
the tool.
Jun-15Enhanced DG Mapping Tool
online
4.1.1Consult with Connections stakeholders during the development of new or review
of existing technical standards associated with connections activities.Mar-16
All materially changed or new
standards are published externally
for consultation
4.1.2Ensure consistency of application of standards, procedures and policies across
EPN, LPN and SPN - we will fully investigate examples of inconsistencies.Ongoing
No complaints related to
inconsistency of application
4.2.1
Continue to develop initiatives through our Future Networks team, ensuring that
successful initiatives are seen through to business as usual - i.e. Flexible
Urban Networks LV and Kent Active System Management.
OngoingPositive feedback at DG Forums
and Innovation events
4.2.2 Monitor development of all projects and share findings with key stakeholders. OngoingProvide Innovation updates at DG
Forums
4.3.1 Roll out Flexible DG Connections to Eastbourne/Lewes zone. Jul-15 Roll out in line with Plan
4.3.2 Extend March/Peterborough Flexible Distributed Connections zone. Oct-15 Roll out in line with Plan
4.4.1Publish outcome of review of requirement for non-hard-wired intertripping circuits
between customer's site and our network. Sep-15 Document published
4.4.2Publish policy on completion of harmonic assessments in conjunction with
revised industry codes of practice EU COP.Sep-15 Document published
4.4.3Introduce a Service Level Agreement of 30 working days for provision of fault
level information.Jun-15
% of requests met within SLA
timescale
4.4.4Introduce Service Level Agreement of 20 working days for provision of
switchgear protection settings. Jun-15
% of requests met within SLA
timescale
4.4.5Publish outcome of review of DOC protection settings at key substation sites
that may allow for additional generation capacity.Sep-15 Identified sites reviewed
4.4.6 Publish updated policy standards on use of non-brick built substations. Sep-15 Document published
4.4.7 Review accessibility to network for small scale DG connections. Sep-15 Proposals developed
4.4.8Develop standards/policies and seek feedback (4.1 above methodology) to
support anticipated uptake of roof-mounted systems.Dec-15 Proposals developed
Transparency of
charges5.1
Improve the explanation of connections charges by introducing a clearer
breakdown of the cost elements included in a quotation.Sep-15
Full implementation of improved
quotation breakdown format
complete business-wide
A&D charges 5.2 Continue to support case for re-introduction of A&D charges. Dec-15Visibility of a plan to re-introduce
A&D charges
Collaborative
reinforcement5.3
Seek stakeholder views on approaches to collaborative reinforcement and if
appropriate develop policies to facilitate.Ongoing
Options/initiative explored at DG
Customer Forum - outcome
published
6.0
Ch
oic
e
Convertible Quotes 6.1Introduce 'convertible quotes' as the standard connection offer for all schemes
comprising contestable and non-contestable works.Sep-15 Full implementation
7.1.1Play a key role in national DG events and arrange specific UK Power Networks
events to meet needs of customers.Ongoing
UK Power Networks to be seen as
a point of reference for DG issues
7.1.2Ensure all feedback/communication from customers is considered and used to
inform our current and future plans.Ongoing All asks/requests tracked
Issues log 7.2Maintain a DG specific Issues Log to record customer feedback and industry
developments and share issues with key stakeholders.Ongoing Issues Log published
4.1
Innovation 4.2
FDG Connections 4.3
1.0
Cu
sto
mer
Serv
ice
2.0
Ap
pli
cati
on
pro
cess
3.0
In
form
ati
on
Pro
vis
ion
4.0
Tech
nic
al
Engagement during
development of new
standards
Clarity on key
technical areas4.4
5.0
Ch
arg
ing
7.0
Feed
back Customer
Feedback
Seminars
7.1
2011. UK Power Networks. All rights reserved 100
KEY DELIVERABLES Q2
Provide an Account Management service to DG
customers with multiple schemes.
Jun-15 Number of new DG
customers signed up to
Account Managed service
Review key customer touch points to ensure
customers receive a best in class experience.
Jun-15 Publish and share findings at
customer workshops
Introduce process to support earlier completion of
Connection Agreements during the application and
design stage of schemes.
Jun-15 % of Connections
Agreements issued in
advance of physical
connection completion
Publish the 'Contracted DG Connections Register'
online.
Jun-15 Contracted DG Connections
Register published
Develop our DG Mapping Tool to provide visibility of
network capacity by including 'Heat Map' functionality
and grid and primary substation capacities in the tool.
Jun-15 Enhanced DG Mapping Tool
online
Introduce a Service Level Agreement of 20 working
days for provision of fault level information.
Jun-15 % of requests met within SLA
timescale
Introduce Service Level Agreement of 30 working days
for provision of switchgear protection settings.
Jun-15 % of requests met within SLA
timescale
Wayleaves/legals Noel Jemma
DG Consent Process
2011. UK Power Networks. All rights reserved
Consent Process
It is Company policy, on all new Connections matters, to obtain the best
available consents from the affected landowners.
In practice, that means:
• Freehold acquisition or long lease (usually 99 years) of all
substation sites
• Permanent easements for electric lines
The latest versions of these standard documents are maintained on the
G81 website.
103
How do we compare with others?
2011. UK Power Networks. All rights reserved
Consent Process
In relation to a number of DG connections, it has been possible to
adapt the approach by applying the existing policy on Consumer
Substations.
A Consumer Substation is a site that forms part of a teed connection, is
installed on the customer’s property and is associated with an electrical
connection to one customer only.
• UK Power Networks does not require a legal estate in the land upon
which a Consumer Substation is installed
104
How do we compare with others?
2011. UK Power Networks. All rights reserved
Consent Process
Due to the nature of these connections, and the fact that the majority of
DG Developments have an anticipated lifespan of 25-30 years, it has
also been possible to adapt the approach in relation to the length of the
term that is to be granted to UK Power Networks.
• UK Power Networks will accept the grant of a substation lease, or
the grant of easements for electric lines, for a reduced term of years
to coincide with the lifespan of the development
105
How do we compare with others?
2011. UK Power Networks. All rights reserved
Consent Process
Following a number of discussions with representatives from the DG
industry, we are developing a “Decision Tree” to assist with the
identification of the landowner consents that UK Power Networks will
require on typical DG developments.
The draft Decision Tree is shown overleaf.
Any feedback would be welcome.
Note: The use of Letters of Authority is dependent upon the
documentation between the Landowner and the Generator containing
adequate rights for our purposes, and being granted for the benefit of
the Generator and those authorised by it.
106
How do we compare with others?
2011. UK Power Networks. All rights reserved 107
Consent Process
Legal Instructions & plans
2011. UK Power Networks. All rights reserved
Legal Instructions & plans
Where it is identified that formal legal rights will need to be granted to
UK Power Networks, you must supply the following to the UKPN
Project Manager:
• Legal Information Form
• Legal Plan
• Agreed Heads of Terms and/or Solar Farm Lease and Easements
109
2011. UK Power Networks. All rights reserved
Legal Instructions & plans
The plan colours for all 3 DNO areas are:
• Coloured PINK, the land to be acquired.
• Edged RED, the land to be retained.
• Coloured BLUE, the land over which access is required for plant
and personnel only.
• Coloured BROWN, the land over which access is required for all
purposes, including cables
• Coloured YELLOW, the land under which the right to place cables
only is required.
• Coloured GREEN, the land over which rights for ventilation is
required.
• RED lines, squares, dots and T marks, for overhead lines, towers,
poles and stays.
110
2011. UK Power Networks. All rights reserved 111
2011. UK Power Networks. All rights reserved
Legal Instructions & plans
In the case of cable easements, always subject to variation depending
on the circumstances, we suggest the following easement widths:
• LV, HV or single 33kV cables – 3 m wide
• Dual 33kV cables – 5 m wide
• 132 kV cables – 6 m to 10 m wide
112
Statutory Consents
2011. UK Power Networks. All rights reserved
Statutory Consents
Note: The above process relates to landowner consents only.
If the transaction is following the CiC route, the ICP/Generator is also
responsible for obtaining all other necessary consents associated with
the project, including, but not limited to:
• Planning Consent
• Common Land & Village Green Consent
• Environmental Consents (Natural England, Environment Agency,
Local Flood Authority)
• Archaeological Consents (English Heritage)
• Pipelines (National Grid Gas, other Utilities)
• Network Rail
114
DG Mapping Tool
Steve Halsey and Meghana Garg (IS)
2011. UK Power Networks. All rights reserved
Original DG Mapping Tool
116
2011. UK Power Networks. All rights reserved
Enhanced to include heat map
117
2011. UK Power Networks. All rights reserved
Network constraints added
118
2011. UK Power Networks. All rights reserved
Contracted Connections Register
119
Questions & Answers
120
2011. UK Power Networks. All rights reserved
Where are we now? Your views on seven key areas
121
5.00
5.50
6.00
6.50
7.00
7.50
8.00
8.50
9.00
9.50
10.00
Our information provision
The application process
Our approach to charging
The choice you have
Technical
Our engagement with you
Feb-15 Jun-15
Thank You