New Distributed Generation Customer Forum - UK Power Networks · 2015. 8. 10. · Last forum -...

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


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


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


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


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

http://www.google.co.uk/url?sa=i&rct=j&q=&esrc=s&frm=1&source=images&cd=&cad=rja&uact=8&ved=0CAcQjRw&url=http%3A%2F%2Fwww.cranfield.ac.uk%2Fcourses%2Ftraining%2Frenewable-energy-policy-modelling-and-analysis-of-potential.html&ei=EmvCVND9GsK5aee2geAC&bvm=bv.84349003,d.ZGU&psig=AFQjCNHY_iwwX7RM_ffdK2s-jhv0tdHMBA&ust=1422113897389909


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


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”


>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


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


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

[email protected]

[email protected]

16

IMPORTANT – OUR NEXT DG CUSTOMER FORUM WILL BE HELD AT A NEW LOCATION IN HOLBORN

mailto:[email protected]

mailto:[email protected]


The Voice of the Networks – DG Fora 2015

17

http://www.energynetworks.org/events/networking-workshops-and-fora/overview/distributed-generation-fora-2015/distributed-generation-fora-2015.html


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


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


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


Number of 132kV

Connections 5 2 15

Capacity of 132kV



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


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


Statement of Works GSP Sites EPN

27


EPN Heat Map

28 Eastern Power Networks capacity map

https://www.ukpowernetworks.co.uk/internet/en/our-services/documents/HQ-2000-4702-M.141205.pdf


Statement of Works GSP Sites SPN

29


SPN Heat Map

30 South Eastern Power Networks capacity map

https://www.ukpowernetworks.co.uk/internet/en/connections/documents/FDG_SPN_EOI_diagrams_Kemsley - Sittingbourne.pdf


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


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


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


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


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


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


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


corners must just




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


corners must just




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


corners must just




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.


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).



• 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

https://www.ukpowernetworks.co.uk/internet/en/our-services/documents/UK Power Networks Management of Capacity Consultation Response 20141223.pdf



• 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



• 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


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


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


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


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 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)


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


Expression of interest (non-

binding) for currently

constrained area initiating

01 July 2015

Single Line Diagram Kemsley GSP


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)


• 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


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


• 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


Technical Break-Out Session

• Network Constraints

»Circuit Complexity

»High Volts

• National Grid

»Challenges

• Innovation

• What's next? Storage? New tech?

88


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


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


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


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


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


ICE plan

• Single plan covering all

segments

• Key DG activities are

–DG mapping tool

–Roll-out of Flexible

DG connections

–Community energy

focus


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


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


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


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?


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



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



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



Consent Process

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



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



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


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)


Original DG Mapping Tool

116


Enhanced to include heat map

117


Network constraints added

118


Contracted Connections Register

119

Questions & Answers

120


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

New Distributed Generation Customer Forum - UK Power Networks · 2015. 8. 10. · Last forum -...

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