eirgrid transmission forecast statement 20102016

TRANSMISSIONFORECAST STATEMENT2010-2016

Disclaimer

E i r G r i d , t h e T r a n s m i s s i o n S y s t e m O p e r a t o r ( T S O ) f o r I r e l a n d , m a k e s n o w a r r a n t i e s o r

r e p r e s e n t a t i o n s o f a n y k i n d w i t h r e s p e c t o f t h i s d o c u m e n t , i n c l u d i n g , w i t h o u t l i m i t a t i o n , i t s

q u a l i t y , a c c u r a c y a n d c o m p l e t e n e s s . T h e T S O d o e s n o t a c c e p t l i a b i l i t y f o r a n y l o s s o r d a m a g e

a r i s i n g f r o m t h e u s e o f t h i s d o c u m e n t o r a n y r e l i a n c e o n t h e i n f o r m a t i o n i t c o n t a i n s . U s e o f

t h i s d o c u m e n t a n d t h e i n f o r m a t i o n i t c o n t a i n s i s a t t h e u s e r ’ s s o l e r i s k . I n a d d i t i o n , t h e T S O

s t r o n g l y r e c o m m e n d s t h a t a n y p a r t y w i s h i n g t o m a k e a d e c i s i o n b a s e d o n t h e c o n t e n t o f t h i s

d o c u m e n t s h o u l d c o n s u l t t h e T S O i n a d v a n c e .

Copyright Notice

A l l r i g h t s r e s e r v e d . T h i s e n t i r e p u b l i c a t i o n i s s u b j e c t t o t h e l a w s o f c o p y r i g h t . T h i s p u b l i c a t i o n

m a y n o t b e r e p r o d u c e d o r t r a n s m i t t e d i n a n y f o r m o r b y a n y m e a n s , e l e c t r o n i c o r m a n u a l ,

i n c l u d i n g p h o t o c o p y i n g w i t h o u t t h e p r i o r w r i t t e n p e r m i s s i o n o f t h e T S O .

FOREWORD

E i rGr i d i s p lea s ed t o pr es ent t h i s Tr ans mi s si on For ec as t St atement ,

which has been prepared in accordance wi th the provis ions o f

Sect ion 38 of th e E l ectr ic i ty Regulat ion Act , 1999. I t supersedes

Transmiss ion Forecast St atement 2010-2016 Vers ion 1 .0, p ub l i s h ed

in December 2009.

In T ransmi ss i on For ecast St atement 2010-2016 Vers ion 2 .0 we present informat ion

t h at s h o ul d h el p c u s t o m e r s w h o a r e c o n s i der ing connect ion o f a g enerator or a new

large load to the gr id . We quant i fy the extent o f opportuni t ies av ai lable for demand

connect ions at a rang e of loca t ions throughout the gr id, pres ent the opportuni t ies for

g enerator connect ions ident i f ied through t h e G a t e 3 pro c e s s a n d d i s c us s t h e

generat ion opportuni t ies ar isi n g f ro m E i r G r id ’ s g r i d dev el op m e n t st r ateg y , G R ID 2 5 .

Those who ar e consider ing connect ing to the gr id are adv ised to cont act E i rGr id for

f u r th er i n f orma t i o n .

We inc l ude a comprehensive rev iew of ex ist ing and pl anned t ransmiss ion network

data , dema nd data and generat ion data , as wel l as a sh or t c i rcu i t anal ys is based on

t h e m os t r ec e n t d at a pro j e ct i o n s. We p r ov i d e an u p d a t e d set o f n et w ork d a t a, m a ps

and d iagrams which prov ide deta i ls o f th e t ransmiss ion network and how i t is

proposed to be developed over the 2010-2016 per iod.

F i n al l y , i t is o u r a i m th at th e i nf o r ma t i o n c o n t ain e d i n th is d o c u m e n t i s i n f o r ma t i v e,

p e r t i n e n t a nd a c c e ss i bl e. W e w el c o me a n d v al u e y o u r f e e d ba c k o n t h e p r e s e nt a t i o n,

s ty le a nd con ten t o f th i s T r an smi ssi on F o r ec a st St a t e m e nt a t a l l t i m es .

D e r m ot B y r ne

C h i ef Ex e c ut i v e, E i r Gr i d

table of contents

TRANSMISSION FO RECAST STATEMENT 2010-2016

CONTENTS PAGE

FOREWORD

SUMMARY

1 INTRODUCTION 1-1

1 .1 Out l ine o f the Transmission Forecast Statement 1 -1

1 .2 T reatment Of The Si ngle E lect r ic i ty Market 1 -2

1 .3 T reatment Of In terconnect ion 1 -2

1 .4 Data Management 1 -3

1 . 5 P u b l i ca t i o n 1 -3

2 THE ELECTRICITY TRANSMISSION NETWORK 2-1

2.1 O v er v i ew of t h e E l ect r i c i t y Tra ns mis si on Net w or k 2-1

2 .2 Ex is t ing Connect ions wi th Northern I re land 2-2

2 .3 P lans For T ransmissi on System Development 2 -3

2 .4 Connect ion of New G enerat ion St at ions 2-7

2 .5 Connect ion of New Inter face Stat ions 2-9

2 . 6 D e t ai l e d Netw o r k I n f or ma t i o n 2 - 1 0

3 DEMAND 3-1

3 .1 F or ecasts of T r an smi ss i on Peaks 3 -1

3 . 2 C o m p a r is o n w i th Pr ev i o us D e ma n d For e c a st 3 - 2

3 .3 Forecast Demand at T ransmi s si o n I nt e r fa c e S ta t ion s 3 - 2

3 . 4 D e ma nd Pr o f i l es 3 -3

4 GENERATION 4-1

4 .1 Ex is t ing and P l anned G r id-Connected Generat ion 4-1

4 . 2 P l a n n e d R et i r e m e n t /D iv es t i t u r e O f G en e r a t i o n P l ant 4 - 2

4 .3 Embedded Generat ion 4-3

4 .4 Wind Generat ion 4-3

5 TRANSMISSION SYSTEM PERFORMANCE 5-1

5 .1 Forecast Power F l ows 5 -1

5 .2 Compl iance wi th P lanni ng St andards 5 -1

5 .3 Short Ci rc u i t Currents 5 -3


6 OVERVIEW OF TRANSMISSION SYSTEM CAPABILITY 6-1

ANALYSES

6 .1 T ransfer Capa bi l i ty Anal ys es For New Demand 6-1

6 .2 Factor s Impac t i ng On Resul ts 6 -3

7 NETWORK CAPABILITY FOR NEW GENERATION 7-1

7 .1 GRID25 7 -1

7 .2 Gate 3 and Post Gate 3 Generat ion Appl icants 7 -1

7 .3 G enerat ion Connect ion Opportu ni t i es Cr ea t ed by G RID 25 7 -2

7 .4 Impact o f Gate 3 and Post Gate 3 on Capabi l i ty for New Generat ion 7 -2

8 NETWORK CAPABILITY FOR NEW DEMAND 8-1

8.1 Incrementa l T ransfer Capa bi l i ty Resul ts For New Demand 8-1

8 .2 Opportuni t i es For New Demand 8-3

8 .3 Impact Of Changes S inc e The Data F reeze 8-4

8.4 How To U s e The Informat ion For Dema nd 8-4


APPENDICES

A MAPS AND SCHEMATIC DIAGRAMS A-1

A .1 Networ k M ap s A-1

A .2 Short Bus Codes A-4

A .3 Schemat ic Networ k D iagrams A-6

B NETWORK CHARACTERISTICS B-1

B . 1 C h a r ac t er i s t i c s Of Th e E x i s t i n g N et w or k B - 3

B.2 Changes In Networ k Ch ar acter ist ics B-14

C DEMAND FORECASTS AT INDIVIDUAL TRANSMISSION C-1

INTERFACE STATIONS

D GENERATION CAPACITY AND DISPATCH DETAILS D-1

D.1 G enerat ion Connected To Th e Tra nsmi s si on System D -1

D.2 Wind Generat ion Connected To Th e Dist r i but i on Syst em D -6

D .3 G enerat i on D i spatc h Deta i l s D -10

E SHORT CIRCUIT CURRENTS E-1

E .1 Background E-1

E .2 Analysis E -2

E .3 Resul ts E -3

F ADDITIONAL INFORMATION ON OPPORTUNITIES F-1

G STUDY METHODS G-1

G.1 Incrementa l T ransfer Capa bi l i ty St udies For Demand G-1

H ABBREVIATIONS AND GLOSSARY H-1

H . 1 A b b r e vi at i o ns H - 1

H . 2 G l o s s ar y H - 3

I REFERENCES I-1

J POWER FLOW DIAGRAMS J-1

J . 1 Guide T o T he Power F l ow Di ag rams J - 1

K SIZE A3 GEOGRAPHICAL MAPS K-1


TABLES Table S-1 Forecast o f Peak Transmissi on Demand S-3

Tabl e S-2 Summary of G enerators wi th S igned Connect ion Agreements before

J u l y 2 0 0 9 S-4

T a b l e 2 - 1 T o t a l L e ng th o f E x i st i ng G r i d C i rc u i t s a s a t J u l y 0 1 s t 2009 2-1

Tabl e 2-2 Tota l G r id T ransformer MVA Capaci ty as a t Ju l y 01 s t 2009 2-2

Tabl e 2-3 Tota l React ive Co mpensa t i on a s at Ju l y 01 s t 2009 2-2

Tabl e 2-4 P lanned Connect ion Me th o d s o f F u t ur e G e n er a t ors 2 - 7

Tabl e 2-5 P lanned Connect ion Methods of F u tur e Wi n d F ar m s A gr e e d A f t er th e

D a t a Fr e e z e 2-9

Tabl e 2-6 P lanned 110 kV Stat ions 2-9

Table 3 -1 T ransmiss ion Demand Forecast , MW 3-1

Table 3 -2 Compar ison of Peak Dema nd Forecast wi th Prev ious TFS, MW 3-2

Tabl e 4-1 P lanned Gr id-Connected Generat ion as at Ju l y 01 s t 2009 4-1

Table 4-2 Ex is t ing Embedded Generat ion as at Ju ly 01 s t 2009, MW 4-3

Tabl e 4-3 Ex is t ing and Commit ted Wind Capaci ty Tota ls , MW 4-4

Tabl e 4-4 G ate 2 Wind G e nerat i on Ar ea Tot al s 4 -5

T a b l e 4 - 5 G at e 3 G e n e ra t i o n Ar e a Tot al s 4 - 6

Table 5 -1 Standard Equipment Rat ing and M axi mum Desig n Short C i rc ui t

Currents 5 -4

Table 7 -1 Capabi l i ty for New Generat ion for each reg ion, MW 7-2

Table 8-1 Capabi l i ty for Addi t ional Demand at 110 kV Stat ions, MW 8-2

Table A-1 Shor t Bus Codes A-4

Tabl e A-2 Schemat ic Leg end A-7

Tabl e B-1 Nominal and Refer enc e Vol ta g e Lev els B -2

T a b l e B - 2 C h a r ac t er i s t i c s o f Ex i st ing 4 00 kV L ines B -3

T a b l e B -3 C h a r ac t er i s t i c s o f Ex i st in g C ro s s -B o rde r 2 7 5 k V L i n e s B - 3

T a b l e B - 4 C h a r ac t er i s t i c s o f Ex i st ing 220 kV L ines and Cabl es B-4

T a b l e B - 5 C h a r ac t er i s t i c s o f Ex i st in g 1 1 0 k V L in e s a n d C a bl e s B - 5

T a b l e B - 6 C h a r ac t er i s t i c s o f Ex i st in g 4 0 0 / 2 2 0 k V G r i d Tr a ns f o r m er s B - 1 0

T a b l e B - 7 C h a r ac t er i s t i c s o f Ex i st in g 275/220 kV G r id Transformers B-10

T a b l e B - 8 C h a r ac t er i s t i c s o f Ex i st in g 2 2 0 / 1 10 k V G r i d Tr a ns f o r m er s B - 1 1

Ta bl e B -9 Ch a r ac t er i s t i c s o f Ex i st ing P ower F l ow Contr ol l er B -12

T a b l e B - 1 0 C h a r ac t er i s t i c s o f Ex i st ing React ive Compensat ion B-12

Tabl e B -11 Ch ang es in C i rcui t Char a c t er is t i c s Ex p e ct e d A f t er Ju l y 0 1 s t 2009 B-14

Tabl e B -12 Ch ang es in C i rcui t Char a c t er i s t i c s Ex p e ct e d i n 201 0 B - 1 6

Tabl e B -13 Ch ang es in C i rcui t Char a c t er i s t i c s Ex p e ct e d i n 20 1 1 B - 1 8

Table B-14 Changes in C i rcui t Charac t er is t i c s Ex p e ct e d i n 201 2 B - 1 9


Tabl e B -15 Ch ang es in C i rcui t Char a c t er i s t i c s Ex p e ct e d i n 20 1 3 B - 2 0

Tabl e B-16 Chang es in C i rcui t Charac ter is t ics Expected Beyond 2013 B-22

T a b l e B - 1 7 C h a r ac t er i s t i c s o f G r i d Tr ansfor mers Expect ed in 2009 B-23



Tabl e B-20 Character is t ics o f Gr id Tr ansfor mers Expect ed in 2012 B-24

Tabl e B-21 Character is t ic s o f Gr id Tr ansfor mers Expect ed in 2013 B-24

Table B-22 Charac ter is t ics o f Gr id Tr an sfor mers Expected Beyond 2013 B-25

T a b l e B - 23 C h a r ac t er i s t i c s o f R e ac t iv e C o m pe n sa t i o n Ex p e cte d i n 2 0 1 0 B - 2 5

Tabl e B -24 Ch ar ac t er i s t i c s o f Reac t iv e Compensat ion Ex pected in 2016 B-25

Table C-1 Demand Forecasts at T i me of Wi nter Peak C-1

Table C-2 Demand Forecasts at T i me of Summer Peak C-4

Table C-3 Demand Forecasts at T i me of Summer Val ley C-7

T a b l e D - 1 M a xi m u m E xp o r t C ap a ci t i e s o f Ex is t ing and Commit ted Transmissi on-

Connected Generat ion D-2

Tabl e D-2 Maximum Cont inuous Rat ing of Ex i s t ing and Commi t t ed Tr ansmi s si on-

Connected Generat ion D-4

Tabl e D -3 Ex ist i ng and Commi t t ed D i st r i but ion-Connected Wind Farm Capaci ty D-6

T a b l e D - 4 D i sp a tc h P r of i l e s - Sh o rt C i r c ui t a n d D e m a n d O p por t u ni t y A n al y s e s D - 1 1

Tabl e E -1 Sh ort C i rc ui t Cur rent Leve l s - St andard Equi pment Rat ing E -2

Table E -2 Short Ci rc u i t Currents for Maximum and Mi nimum Demand in 2010 E -3




FIGURES F igure S-1 Capabi l i ty for New Demand in 2013 and 2016 S-6

F ig u r e 2 - 1 E x is t i n g C r os s - B or d e r C i r c ui t s 2 - 3

F i g u r e 3 - 1 W e e kl y P e a k V al u e s f or Yea r 20 0 8 3 - 4

F ig u r e 3 - 2 D a i l y D e m a nd P r o f i l e s f or Y ea r 2 0 0 8 3 - 4

F ig u r e 4 - 1 G r ow th i n Win d C a p ac i t y , 1 9 9 2 t o 2 0 14 4 - 4

F ig u r e 4 - 2 G at e 2 Wi n d G e n e ra t i o n A r e a s 4 - 5

F ig u re 4 -3 Gate 3 Wi n d Gen erat i on Areas 4-6

F ig u r e 5 - 1 N e t w or k P er fo r m a n c e i n 201 0 5 - 2

F ig u r e 5 - 2 N e t w or k P er fo r m a nce in 2013 and 2016 5 -3

F ig u r e 5 - 3 G r i d B u s ba r S h o rt Ci rc u i t C u r re n t s f or Wi n t er P e a k 2 0 1 3 5 - 5

F igure 6-1 I l lust rat ion o f Typi cal Step Change in Network Capaci ty 6 -2

F ig ur e 6-2 D emand Pr of i l e at Typi cal St at i on 6-3

F igure 8-1 110 kV Stat ions Studied for Demand 8-1

F igure 8-2 Capabi l i ty for New Demand in 2013 and 2016 8-4

F igure A-1 T ransmiss ion System 400 kV, 220 kV and 110 kV as a t as at Ju ly 01 s t

2009 A-2

F ig ure A-2 P lanned Transmiss ion System 400 kV, 220 kV and 110 kV as at

D e c e m b er 3 1 s t 2016 A-3

F ig u r e A -3 S c h e m at ic Di ag r a m o f the E x i st i ng and P l a n n e d G r i d a t E n d o f 2 0 09 A - 8

F ig u r e A - 4 S c h e m at ic Di ag r a m o f the E x i st i ng and P l a n n e d G r i d a t E n d o f 2 0 1 0 A - 9

F ig u r e A - 5 S c h e m at ic Di ag r a m o f the E x i st i ng and P l a n n e d G r i d a t E n d o f 2 0 13 A - 1 0

F ig u r e A - 6 S c h e m at ic Di ag r a m o f the E x i st i ng and P l a n n e d G r i d a t E n d o f 2 0 1 6 A - 1 1

F ig u r e D - 1 G e og r ap hi cal L o ca t i o n o f E x is t ing and P l anned Wind Farms at Ju l y 01 s t

2009 D-9

F igure E -1 Typical Short Ci rcui t Curr ent E -1

F igure G-1 I l lust rat ion o f Incr ementa l T ransf er Capabi l i ty Study Method for G-3

Demand

F ig u r e J - 1 P o w er F l ow D i ag ra m S um m e r P e a k 201 0 J - 2

F ig u r e J - 2 P o w er F l ow D i ag ra m S um m e r V al l e y 2 0 1 0 J - 3

F ig u r e J -3 P o w er F l ow D i ag ra m W i nt e r P e a k 2 0 10/ 1 1 J - 4



F ig u r e J - 6 P o w er F l ow D i ag ra m W i nt e r P e a k 2 0 13 / 1 4 J - 7



F ig u r e J - 9 P o w er F l ow D i ag ra m W i nt e r P e a k 2 0 16/ 1 7 J - 1 0

F igure K-1 T ransmiss ion System 400 kV, 220 kV and 110 kV as at Ju ly 01 s t K -2


2 0 0 9 ( A3 )

F igure K-2 P lanned Tr ansmissi on System 400 kV, 220 kV and 110 kV as a t K -3

D e c e m b er 3 1 s t 2016 (A3 )

summary


S-1

SUMMARY

Introduction

The Transmiss ion Forecast Stat ement (TFS) des c r i bes t h e st a t u s of t h e t r a n s mi s si on g r i d

over the seven-year per iod f rom 2010 to 20 16. I t pr ov ides in format ion to customers

e x a m i ni ng th e p ot e n t i a l o f t he gr id f r o m t he e lect r ic i ty generator or la rge consumer

perspect ives. The tech nica l in format ion is prov ided to help customers ident i fy and ev al uate

t h e o p p or t un i t i e s a v ai l ab l e f o r c o n ne c t i n g t o o r ma ki ng us e of th e t r a nsmi s si on s ystem a nd

t o a l l ow th em, i f des i r ed , t o u n d er ta k e th e i r ow n p o w er f lo w a n al y s e s. T h e T F S pro v i de s

i n f o r ma t i o n a b o u t p ot e nt i a l n et w or k c o n s tr a i nt s which sh ould be in format ive for customers

i n t e n di n g t o p a r t i c i p at e in th e e l ec tr ic i t y m ar k e t .

In th is st at emen t the T r an smiss ion System Operator (TSO) updates the informat ion

publ ished in ear l ier T ransmissi on Forecast St ateme n t s i n l i gh t of d ev el op m e n t s t h at h av e

e i ther taken p lac e or are cur rent ly schedule d t o be c o m pl et e d o v e r th e c o mi n g y e ar s .

Overview of Information Provided

The format of T ransmiss ion Forecast Statement 2010-2016 Vers ion 2 .0 i s a s f o l l o ws :

• TFS 2010-2016 Ver 2 .0 undertakes a comprehen s i v e r e v i ew o f e x i st i ng a n d p l a n ned

t ransmi ssion network da ta and the ex is t i ng and pro jected demand and genera t i on da ta .

The in format ion is presented in th e form of maps, network d iagrams, data tables and

n e t w o rk m o del s wh ic h are i n e l e ct r o ni c f o r ma t .

• TFS 2010-2016 Ver 2 .0 inc ludes a sh or t c i rcu i t a n a l y si s t o d e t e r mi n e th e m ax i m u m a n d

minimum short c i rcui t levels a t each 110 kV, 220 kV and 400 kV busbar on the

t r a ns mi s si on s ys t em, for th ree st ag es of th e sev en year per i od c ov ered by th e TFS –

2010, 2013 and 2016.

• TFS 2010-2016 Ver 2 .0 conta ins the resul ts o f analys is to quant i fy the Incrementa l

T ransfer Capa bi l i ty ( I TC) l ikely to be ava i labl e between var ious par ts o f the gr id . Th is

i n f o r ma t i o n i s a g e n er al g ui d e t o p o t e n t i a l d em a n d c u s t ome r s wh o ar e c o n si d e r ing

c o n n e c t i n g to th e gr i d .

• E i rGr i d ca r r ied o u t t h e s h o rt c i r c ui t a n d ITC an al ys is for TFS 2010-2016 Ver 2 .0 and

updated the network models and tables based on data as know n on the 01 s t o f J u l y 2 0 09 .

T h e da t a was “ f r oz e n ” at t h i s p oi n t .

• TFS 2010-2016 Ver 2 .0 presents the opportuni t i es f o r g e n er at o r c o n n e ct ion s i d e n t i f ie d

t hr o u gh th e G a t e 3 p roc e s s a n d out l i n e s th e generat ion opportuni t ies ar is ing f rom

E i rGr i d’ s g r id d ev e l o p m ent st r at eg y , G R I D 2 5 .


S-2

The Commiss ion for Ener gy Regulat ion (CER) h a s a p p r ov e d t h i s f or m a t i n a c c or d a nc e w i t h

the requ i r emen ts of the E l ect r i c i ty Regulat i on Ac t 1999.

The National Grid

T h e n a t i o n al g r i d pl a y s a v i t a l r o l e i n t h e s up pl y o f e lec t r ic i ty . In s imple terms, i t t ransports

power f rom generators to demand centres using a syst em compr is ing 400 kV, 220 kV and

110 kV networks. The 400 kV and 220 kV networks f o r m t h e b a c k b o n e o f t h e g r i d . T he y h ave

h igher power car ry ing capac i ty and lower losses than the 110 kV networ k. The 400 kV l ines

c r o s s t h e c ou n t r y pr o v i di n g a h i g h ca p a ci t y path for power f lows between nor th and south

Dubl in , Galway and the Moneypoint generat ion s tat ion in Co. C l are . The 220 kV ne twork

c o m p ri s e s a n u m b e r o f s i n gl e c i r c ui t l o o p s a r o un d t h e c o u nt r y . Th e 1 1 0 k V n e t wo r k i s t h e

m o s t ext e n s iv e p a rt of the gr id , r e ac hi n g i nt o e v ery c o u n t y i n th e R ep u b l i c o f I r e l a n d .

The gr id is p lanned and developed to ensure i t meets proj ec ted t ransmiss ion needs whi le

m a i n t ai n i ng i t s p er f or m a n c e w i t h i n d e f i n e d r e l iabi l i ty st andards. The analysis o f cur rent

per f or manc e i ndic at es th at th e netw or k i s w i th i n s tandards in most ar eas at th is t ime. To

cont inue to meet st and ar d s, i n th e cont ext o f forecast demand and new generat i on

connect ions, there is a requi rement for ongoi ng d ev el o p me n t t o r e i n for c e th e g r id . T h e

t r a n s mi s si on d e v el o p m ent p r oj e ct s , s e l ec t e d a nd p l a n n e d by t h e T SO as a t t h e t i me o f t h e

TFS 2010-2016 data f reeze date ( J u l y 2009) , a re l is ted in Sect ion B.2 of Appendix B and are

inc l u de d i n the sh ort c i rc u i t an d ITC anal yses car r ied out for TFS 2010-2016 Ver 2 .0 .

P r oj e ct s s elec t e d a n d pla n n e d s i n c e J u l y 2 0 0 9 are l i s t e d i n Sec t i o n 1 .4 .

Single Electricity Market

In November 2007, a S ingle E l ect r ic i ty Market ( S E M ) w a s e s t a b l i sh ed o n t h e i s l a n d o f

I r e l and. Th e a l l - is land w h ol esal e e l ect r i c i t y m ar k e t a l l ow s b o t h N or th er n I r e l a n d and t h e

Republ ic o f I re l and to benef i t f rom increased compet i t ion, reduced energy costs and

i m p r ov e d r e l i a b i l i t y o f s up p l y .

The nat ional gr id is e l ect r ica l l y connected to the t ransmiss ion system of Nor thern I re l and

by means of one 275 kV doubl e c i rcu i t connect ion at Louth and two 110 kV connect ions at

Let terkenny in Co. Donegal and Corrac lassy in Co. Cavan. E i rGr id and Nor thern I re l and

E l ect r ic i ty (N IE ) are p l anning a new 4 00 kV cr oss -bor der c i rcui t , wh ic h is due to be i ns t a l led

b y 2 0 1 2 . T oget h er w i th ot h er r e i nf o rce m e n t s , th e new c i rc u i t w i l l fac i l i ta te a g r eater deg ree

o f f l ex i bi l i t y i n t h e n e w m a r k et . I n t h e c o n te xt o f th e SEM , a l l c r os s - bor d e r c i rc u i ts a r e

e s s e n t i a l l y in t e r n al c i r c ui t s i n th e n ew m ar k e t .

Interconnection

I n J u l y 2 0 06, M i ni s te r N o e l D e mp sey T D , th e n M i n is t er f or C o m m u n i ca t i o ns , M ar in e a n d

Natural Resources, requested th at th e Commissi on for Energy Regulat i on (CER) ar range a

c o m p e t i t i o n t o s e c ur e t h e c o n s tr uc t io n o f a 5 0 0 M W E as t - W e st i nt er c o n n e ct o r b e t w e e n

I r e l a n d a n d G r ea t Br i t a in . T h e C E R w a s a l s o r eq u e s t e d t o ins t r uc t th e T S O t o c a rr y o u t t h e


S-3

tech nica l work o f select ion o f a sub-sea rout e and other s i tes for the const ruct ion o f the

i n t er c o n n e cto r a n d n e cess a r y gr i d re inf o r c e m e nt w o r k s .

As recommended by the TSO, the CER has s i nce approv ed the ch oi ce of Woodland as the

c onnec t i on poi nt on the I r i sh system f or th e in terconnector . Deeside in Nor th Wales has

been se lected as the connect ion point on the Br i t i s h s ys t e m . T h e i n t er c o nn e c t o r i s e xp e c t ed

t o b e i n p l a ce b y 2 0 1 2 .

Demand Forecasts

The pro jec t ions o f demand for e l ect r ic i ty ar e la rgel y based on forecasts o f economic grow th

p r o d u c ed by t h e E c o no m i c a n d Soc i al R es e ar ch Inst i tute (ESRI ) . Th e pr o ject ions are

c o m p a t i bl e w i th p r ov i s ion a l d e m a nd f i g ur e s int e n d e d f o r i n c l u si o n in t h e G e ner a t i o n

Adequacy Report 2010-2016.

T h e g r i d mus t b e c a pa b l e of t r an s p o r t i ng pow e r f l o w s f o r v ar y i ng l ev el s of d e m a n d .

H ow ev er , the f low at peak demand i s f r eq uent l y, a l th ough not exc l usi ve l y , th e most

onerous. The proj ec t ions o f demand f l ows at peak ar e di scussed in Chapter 3 . Tabl e S-1

shows the forecasts o f peak t ransmission demand for the years 2010 to 2016. Th ese ar e

equivalent to pro ject ions o f peak ex ported generat ion requi rements . Appendix C pr esents

forecasts o f demand at each st at ion connected to the gr id . Forecasts of t ransmiss ion f lows

at peak take account o f non-wind embedded generat ion. Because of i ts s ize and var iabi l i ty ,

t ransmi ss ion and d is t r ibut ion-connec t ed wi nd g ener at ion i s model l ed ex pl i c i t l y i n t h e

anal yses c a rr i ed out for th i s TFS.

I n o v e r al l t er m s , t h e T S O e x p e ct s t h at t h e pea k dem a n d w i l l i n c r e a se b y a p p r ox i m at ely 2 . 0 %

e a c h y ea r o v e r t h e per i o d of t he T F S , w hic h is 0 . 9 % l o w er t han t h a t ex pec t e d i n

T ransmiss ion Forecast Statement 2008-2014 . As such, the peak proj ec t ions to 2016 are

l o w er t h a n for t h e s a me y e a r s i n Tr ans mi s si on For ec as t St atement 20 0 8-20 14.

Table S-1 Forecast of Peak Transmission Demand

Year P e a k D e mand ( MW )

20 10 4 , 63 6

2011 4 ,725

2012 4 ,848

2013 4 ,941

2014 5 ,03 7

2015 5 ,134

2016 5 ,233


S-4

Generation Connections

At the t ime of the data f r eeze ( Ju l y 2009) , so me 7 ,250 MW (net ) o f generat ion capa ci ty was

i n s t al l e d , o f w h i ch 6 , 4 54 M W i s c o n n e c t e d t o the n a t i o na l g r i d a n d 7 9 6 M W i s c o n ne c t e d

d i r ec t l y t o th e d i st r i but ion syst em.

N e w g e n e r at o r s wi th s i g n e d c o n ne c t i o n ag r ee m e n t s ar e i n c l u d e d in t h e sh o rt c i r c ui t

analysis for th is st atement . Tabl e S-2 summar ises the planned connect ions as a t the

beginning of Ju ly 2009, when data was f rozen for the purposes o f TFS model updates.

T a b l e S - 2 S um m a r y of G en e r a t or s wi th Sig n e d C on n e c t i o n Ag re e m e n t s b e for e J u l y 2 0 09

Type of G enerat ion Connected to No. o f Connect ions M W

Thermal T ransmiss ion 6 1 ,535

Wind Farm Transmiss ion 14 582

Thermal D ist r i but ion 3 4 .4

H ydr o D i st r i but i on 1 0 .4

Wind Farm Dist r i but i on 112 843

Tot a l 13 6 2, 9 66

T a k i n g a cc ou n t o f t he s e c o m m it t ed connect ions and expected uni t derat ing s, the instal led

capaci ty would be 9 ,968 MW by the end of 20 16, o f wh ich 8,325 MW wi l l be t ransmission-

connected.

I n F e b r u ar y 2 0 0 9 , E SB P o w e r G e n er at i o n c o n f i r med that i t intends to c l ose Poolbeg Uni ts 1 ,

2 a n d 3 a n d t h e st e a m t ur b i n e at M ar i n a b y e a r l y 2 0 1 0 . T h e l ar g er ga s t urb i n e a t M a r in a w i l l

r e m a i n o p era t i o na l .

In Ju ly 2008, i t was announced that the Spa n i sh p o w er c om p a n y , E n des a , h a d agr e e d t o

p u r ch a s e G re a t I s l a n d a n d T a r b e r t gen e r a t i o n s tat ions as wel l as Rhode and Tawnaghmore

p e a k i ng pl ant s f r o m E SB . T h e e x ac t d e t ai l s o f th e f ut u r e o pe r a t i o n o f the s e pl a n t s ha v e y et

to be f ina l i sed by Endesa.

E i rGr id an d ESB Networ ks hav e processed mor e t ha n 1 , 3 0 0 MW o f w i n d g en e r a t i o n

connect ion appl icat ions under the CER’s Gate 2 d i rect ion on wind farm connect ions.

Appl ica nt s that hav e ac cepted thei r o f fers pr io r to the data f reeze have been inc luded in the

model updates and are descr ibed in Chapter 4 and Appendix D.

E i rGr i d a n d E S B N et w or k s ar e c urr e n t l y a s se ss i n g m or e th a n 1 0 , 00 0 M W o f g en e r a t or

connect ion appl icat ions for f i rm access under the CER’ s Gate 3 d i rect ion on the group

p r o c es s i ng s c h e m e f or g e n e r at o r s. I t i s c u r r e n t l y e x p ec t e d t h a t c i r ca 6 , 0 0 0 M W o f

g e n e ra t i o n w i l l r e c ei v e c o n n e c t i o n of f e rs u n d er G at e 3 .

S ince the Ju ly 2009 data f reeze a number o f developments have occurred wi th regard to

p l anned and insta l l ed g enerat ion. Three new c o n v e n t i o na l g e n e r at i on p l a n t s, C u i l l e e n

98.4 MW OCGT pl ant a t Ath lone, Co. West meath , S ui r 9 8 M W O C G T pl a n t a t C ahir , C o .


S-5

T ipperary and Caulstow n 58 MW OCGT Peaking P lant at Caul st own, Co. Louth as wel l as one

70 MW pump ed st orag e p lant a t Knocknagreenan, Co. Cork, have s ig ned non- f i rm

connect ion agreements . As s tat ed in the di rect ion publ i sh ed by th e CER ent i t l ed “D ir ect i on

on Convent ional Of fer Issuance Cr i ter ia and M a tt e rs R e l a t e d t o G at e 3 ” ( R e f er e n c e:

C E R / 0 9 / 1 9 1 ) , t h e f i r m ac c e s s d at e s f o r t h es e pl a n ts h a s be e n d e t e r mine d a s p a r t o f t h e

G at e 3 gr o u p p r oc e s si ng s c h e m e f or gen e r a t or s .

Transmission System Capability Analyses

The nat ional gr i d i s p lann ed to ac c ommodate a nt i c i pa t e d p ow e r f l o w s b as e d o n e x i s t i n g a n d

p l anned g enerat ion and demand connect ions, and on in terconnect ion wi th other

t ransmi ssion systems. Th is TFS examines th e capabi l i ty o f the gr id to accommodat e

addi t ional f lows resul t ing f rom a new demand connect ion based on data descr ib ing the

ex is t ing and p lanned t ransmissi on system “ f roze n” at the beg i nning of Ju l y 2009. Capabi l i ty

is assessed at three st ag es of the seven-year per iod of the TFS - 2010, 2013 and 2016. For

t h e p u rp o s es o f t he a n aly s e s , g e n er at i o n w a s d i sp a t ch e d o n a n a l l - i s l a n d b a s i s i n t h e c a s es

u p o n w hi ch s t u d ies w er e c a r r i e d o ut . T h i s wa s d on e i n o r d e r to r e f l e ct th e m a n n e r i n w hi c h

g enerat i on is d i spat ch ed i n th e SEM .

The locat ions analysed for new demand have been careful ly rev iewed th is year based on

feedback f r om indust ry sources. The chosen sta t i o ns h av e b e e n t a i l o red t o c l o se l y m a t c h

t h e n e e d s o f t h e us e r s . In t ot al , 29 st a t i ons are anal ysed for new demand connect ions.

T h e r e s ul t s a r e u s e f ul t o t h o s e c o ns i d er i ng d e v e l o p m e nt o f a s i g ni f i c ant d e m a n d i n t h e

Republ ic o f I re l and. They prov ide an indicat io n o f l o c at i o n s t h a t ar e c ap a b l e o f a c c e p t i ng

new demand connect ions wi tho u t th e n e e d f or f u r th e r r e i n f or ce m e n t of t h e gr i d .

Opportunities for New Demand

The gr id is p l anned and developed to meet forecast demands in a l l pa r ts o f the country . The

demand forecast for each 110 kV st at ion is a propor t ion o f the overa l l syst em demand

forecast based on h is tor ical demand d ist r ibut ions. An aver age annual incr ease of 2 .0% is

expect ed at each s tat ion. Th is s tatement examines the capabi l i ty o f se lected 110 kV

s tat ions to accept a new demand addi t ional to these forecasts . I t should be noted that

i n d i v i dua l sma l l d e m a n ds o f u p t o 1 0 M W a r e l i ke l y t o b e a cc o m m o d a t e d a t m o s t l o ca t i o ns .

T o p u t t h i s i n c o n t e xt , a d e m a n d o f 1 0 M W r e p r e se n t s t h e c o n s ump t i o n o f a t y p i cal

p h ar m a c e ut i c a l p l a nt .

As a g ener al r u l e , op p ort uni t y at a par t i c ul ar s t at i on w oul d tend t o r educe over th e cour se

o f the seven years as normal demand grow th uses the ava i lable capaci ty . However , in many

cases demand opportuni t ies impr ove in la ter years as a resul t o f p lanned networ k or

g enerat i on dev el opments.


S-6

The resul ts o f the anal ys is point to opportuni t ies a t the ma jor i ty o f the s tat ions tested .

F igure S-1 sh ows the opportuni t ies for new dema nd in 2013 and 2016. The d iagrams show

t h at th e r e wi l l b e s ig ni f i c a nt d e m a nd o p p o r t u ni t i e s i n m o st p a r ts o f th e c o u n t r y i n b o t h

years . The TSO is cur rent ly cons ider ing p lans for network developments that wi l l improve

opportuni t ies for incr eased demand in Dubl in and the south-east .

<10 MW<10 MW

<10 MW<10 MW

F igure S-1 Capabi l i ty for New Dema nd in 2013 and 2016

Opportunities for New Generation

Tradi t iona l ly the TFS examines the capabi l i ty of the gr id to accommodate addi t ional f low s

r e s ul t i n g f ro m a n e w g e n e ra t or con n e c t ion b a s e d o n d a t a d e s cr i bi ng t he e x is t in g a n d

p lanned t ransmissi on syst em at the t ime of the data f reeze.

TF S 20 1 0-2 016 Ver 2 . 0 p r esents the opportuni t ies for generator connect i ons ident i f i ed

t hr o u gh th e G at e 3 pr o c es s a n d o u t l ine s t h e g ener a t i o n o p p or t u n i t i e s a r is i n g f r o m E i r G r i d’ s

g r i d d e v el opme n t st r at egy, G R I D 2 5 .

A s u m m a r y o f t h e g en e r a t i o n o pp o r t u ni t i e s i d e n t i f i e d as p a rt o f th e G a t e 3 p r o c es s

i l lust rate that by 2016 the developments associat ed wi th Gr id25 c rea te f i rm capaci ty on the

g r i d t o a cc om m o d a t e m or e t ha n 2 , 000 MW of G ate 3 g e n e ra t io n .

Conclusion

E i rGr i d h as p l a n s i n p l ac e t o c at er f o r t he f or ec a s t n e e d s o f th e gr i d . H o wev er , net w or k

development p lanning is a cont inuous proc ess des igned to meet the ev er changing needs

2013 2016


S-7

for t ransmi ss ion. Connect ion of new g enerat ion and larg e point demands can resul t in a

s t e p ch a n ge i n g r i d req u i re m e n t s a n d i n i ts abi l i ty to operat e wi th in s tandards. In

p a r t i c ul ar , l a r ge g e n e rat o r c o n n e ct ion s c a n g ive r i s e t o the n e e d f o r l a r ge t r a n s mi s si o n

r e i n for ce m ent p ro j ec t s t h at m a y t ak e a l o ng t i m e t o c o mp l et e . D e vel o p e r s wi s hing to

c o n n e c t s h oul d c o ns u l t t h e T S O ea r l y i n t hei r d e v e l op m ent p r oc e s s t o e x p l or e o p t i o ns

r e l a t i n g t o th e i r p r op o s al t h us e na b l in g t i m el y d ec i s i o n ma k i ng .

Those who are consider ing connect i n g g e n er a t i o n o r d e m an d t o t h e na t i o na l g r i d s h o ul d

c ont act th e TSO at i n f o@ e i rgr i d .c om f o r f ur th er i n f or m at i o n.

M e m b e r s o f t h e T r a ns m i ss i o n F o r ec a st St a t e me nt Team. Fr om Lef t to R ight : Tom Gal lery ,

L isa McMul lan and S imon Gr imes .

01introduction1.1 outline of the transmission forecast statement

1.2 treatment of the single electricity market

1.3 treatment of interconnection

1.4 data management

1.5 Publication


1-1

1 INTRODUCTION

Th e nat ional gr i d is a h ig h vo l t ag e system o f n e t w or k s w h i c h t r a ns p o r t s p o w er f r o m

g e n e ra t or s to d e m a n d c en t r e s . Th e f lo w o f p o w er i s d e t er m i ne d b y t h e l ev el s o f d e ma n d a t

a l l pa r t s of t h e s y st e m a n d b y t h e s i z e a n d l ocat ion of generat ion supply ing that demand.

I n t e rc o n n e c t i o n w i t h o ther s ys t e m s ca n b e a sou rc e of g e n e rat i o n o r a d em a n d f or pow e r .

T ransmiss ion Forecast St atement 2010-2016 Ver 2 .0, prepared in accordance wi th Sect ion

3 8 o f t h e E l e ct r i c i t y R eg u l a t i o n A c t , 1 9 9 9 , presents fact ual in format ion on, and cur rent

T ransmiss ion System Operator (TSO) pro ject ions for , the gr id , e lect r ic i ty demand,

g enerat i on, and i nter connec t i on wi t h oth er e l ec t r ic i ty systems. The appendices pr ov ide

c u s t o m er s wi th det ai l e d i n f o r ma t i o n t o c a rr y o ut thei r own power f low anal ysis , i f des i red.

The TSO publ ished i ts G enerat ion Adequacy Report 2010-2016 (G AR) in November 2009. That

d o c u m e n t dea l s wi th the r e quir e m ent f or ad d i t io n a l g e n er at i o n c a pa ci ty t o m e e t f or e c a st

demand ov er the seven-year per iod to 2016. In so far as poss ible the GAR complements the

demand in format ion presented in Tr ans mi s si on For ec as t St atement 2010-2016 .

The TSO publ ished i ts T ransmiss ion Development P lan 2008-2012 in Ju ly 2009 . Th e pl an

prov ides deta i ls o f the networ k developments exp e c t e d t o b e p r og r e ss e d i n t h e 2 0 0 8 -20 1 2

per iod, which ar e accounted for in th is TFS.

1.1 OUTLINE OF THE TRANSMISSION FORECAST STATEMENT

Chapter 2 descr ibes the ex ist i ng t r ansmi ssi on netw or k, i nc l uding connect ions wi th Northern

I re l and, and prov ides a br ief out l ine o f th e TSO’s network development p l ans. Detai led

descr ipt ions o f these plans are presented in T ransmissi on Development P lan 2008-2012,

which was publ ished in Ju ly 2009. These documents present a snapshot o f the development

p l a n s a t a poi n t i n t i m e . H o w ev er , t h e pl an n i ng a n d d e v el op m e n t pr o c es s i s d y n a mi c a n d

m a y b e r ef i ned i n l igh t of m o r e up - t o-d a t e i n f o r ma t i o n . A s s uc h , net w or k d e v el o p m e nt p l a ns

shoul d be conf i rmed wi th the TSO before any business dec is i ons are taken based on the

c o n t e n t o f th i s d oc u m en t . M a p s, s ch e m a t i c di ag r a ms a n d n e t w or k d e t ai l s a re i n c l ude d i n

Appendix A and Appendix B. Geog raphical maps of the t ransmission system are pr ov ided in

A3 format in Appendix I .

Chapter 3 descr ibes the demand forecast s a n d C h a pt er 4 des cr i bes t h e g e ner a t i o n

pro ject ions. Detai ls o f the demand forecast s and generat ion assumpt ions are in Appendix C

and Appendix D respect ivel y .

T h e as s u m p ti o n s pr e s e nted i n Ch a pter s 2 t o 4 for m th e b a si s of t h e sho r t c i r c ui t cur r e nt s

presented in Chapter 5 and the anal ys is o f t rans fer capabi l i t ies desc r ibed and repor ted in

Chapters 6 to 8 . Appendix E presents forecast s h or t c i rc u i t c ur re n t s at a l l g r i d s ta t i o ns .


1-2

C ha pte rs 7 an d 8 con ta i n i n for mat ion on th e opportuni t ies for generator and demand

connect ions.

D i ag r a m s a r e p r e s e n t ed i n A p p e n d i x J w h i ch s h ow t y p ic al p o w e r f l o w s o n a l l gr id c i r cu i t s f or

a number o f d i f ferent condi t ions.

1.2 TREATMENT OF THE SINGLE ELECTRICITY MARKET

In November 2007, a S ingle E l ect r ic i ty Market ( S E M ) w a s e s t a b l i sh ed o n t h e i s l a n d o f

I r e l and. Th e a l l - is land w h ol esal e e l ect r i c i t y m ar k e t a l l ow s b o t h N or th er n I r e l a n d and t h e

Republ ic o f I re l and to benef i t f rom increased compet i t ion, reduced energy costs and

i m p r ov e d r e l i a b i l i t y o f s up p l y .

The nat ional gr id is e l ect r ica l l y connected to the t ransmiss ion system of Nor thern I re l and

by means of one 275 kV doubl e c i rcu i t connect ion at Louth and two 110 kV connect ions at

L e t t er k e n n y i n C o . D o n eg al a n d C o rr a cl a ss y i n Co. Cavan. The TSO and Northern I re land

E l ect r ic i ty (N IE ) are p l anning a new 4 00 kV cr oss -bor der c i rcui t , wh ic h is due to be i ns t a l led

b y 2 0 1 2 . T oget h er w i th ot h er r e i nf o rce m e n t s , th e new c i rc u i t w i l l fac i l i ta te a g r eater deg ree

o f f l ex i bi l i t y i n t h e n e w m a r k e t . I n t h e c o nt ex t o f t h e S EM , a l l c r o ss - b o r d e r c i rc u i ts w i l l

e s s e n t i a l l y b e c o m e i n t er n a l c i rc u i t s i n t h e n e w ma r k e t .

I n o r d e r t o re f l ec t t h e wa y i n wh ic h t h e t r a ns m i ss i o n s y st e ms o f th e R e pub l ic o f I r e la n d a n d

Nor thern I r e l and oper at e, the network was assess ed wi th generat ion d ispatch ed on an a l l -

is land bas is in networ k models . As such, f l ow s of power across cr oss-border c i rcui ts were

p e r m it ted i n t h e sh o rt c i r c ui t a n d p ow e r f l ow a na l y s es c ar r ied o u t f o r TF S 2 0 1 0 - 2 0 16 . I t i s

important to note however that only the per formance and capabi l i ty of the t ransmission

system of the Republ ic o f I re land is considered. The per formance and capabi l i ty o f the

t ransmi ssion system of Nor thern I re l and is addressed in SONI ’s T ransmiss ion System Seven

Year Stat ement .

1.3 TREATMENT OF INTERCONNECTION

I n J u l y 2 0 06, M i ni s te r N o e l D e mp sey T D , th e n M i n is t er f or C o m m u n i ca t i o ns , M ar in e a n d

Natural Resources, requested th at th e Commissi on for Energy Regulat i on (CER) ar range a

c o m p e t i t i o n t o s e c ur e t h e c o n s tr uc t io n o f a 5 0 0 M W E as t - W e st i nt er c o n n e ct o r b e t w e e n

I r e l a n d a n d G r ea t Br i t a in . T h e C E R w a s a l s o r eq u e s t e d t o ins t r uc t th e T S O t o c a rr y o u t t h e

tech nica l work o f select ion o f a sub-sea rout e and other s i tes for the const ruct ion o f the

i n t er c o n n e cto r a n d n e cess a r y gr i d re inf o r c e m e nt w o r k s .

As recommended by the TSO, the CER has s i nce approv ed the ch oi ce of Woodland as the

c onnec t i on poi nt on the I r i sh system f or th e in terconnector . Deeside in Nor th Wales has


t o b e i n p l a ce b y 2 0 1 2 .


1-3

1.4 DATA MANAGEMENT

System development is cont inuously evol v ing. In order to car ry out analyses and to update

the network models and appendices for the TF S 2010-2016 Ver 2 .0, the TSO f roz e a l l data

re lat ing to demand, g enerat ion and the gr i d at t he b e gi n n i ng o f J u l y 2 0 0 9 .

S i n c e t he da t a f r e ez e d a t e , a n um b e r o f c hanges in pro ject ions have emerged. These

changes have been documented and d iscussed in Chapter 2 . The more s igni f icant changes

in pr o ject ions ar e as fo l lows:

Connect ion agreements for 324 MW of T ransmiss ion connected generat ion:

− Cui l leen 98.4 MW OCGT p lant at Ath lone, Co. Westmeat h;

− Sui r 9 8 M W O CG T pl ant a t Cahi r , Co. T i pper ar y;

− Ca ul st ow n 58 M W O CG T P ea ki ng P lant at Ca ul st ow n, Co. Louth ;

− 70 MW pumped st orag e pl ant at Knocknagreenan, Co. Cork .

T h e f o l l ow i ng g r i d d ev e lop m e n t s h ave b e e n i n i t i at e d a s p r oj ec t s :

− U prat i ng of th e Cahi r -D oon 110kV l i ne;

− U prat i ng of th e Gr eat Is l and-W at er f ord No.1 110kV l i ne;

− Uprat ing o f the L i mer ick-M onateen 110kV l ine;

− U prat i ng of th e Cath al een’ s Fal l -Corac lassy 110kV l ine;

− U prat i ng of th e Car r ig adroh i d-Ki l barry 110kV l i ne;

− Uprat ing o f the Coolroe- Inniscar ra 110kV l ine;

− Construct ion o f a new 110 kV s tat ion at Oranmore, Co. Galway which wi l l be

c o n n e c t e d i nt o t h e ex is t in g C a shl a -Ga l wa y N o . 3 1 1 0 k V c i rc u i t ;

− U prat i ng of th e Cashl a -Ennis 110kV l ine.

1.5 PUBLICATION

T h i s T F S i s a v ai la b l e i n p d f for m at o n t h e E i rG r i d w e bs i t e (w w w . ei rgr i d .c o m). For a hard-

c o p y v er s i o n, p l e as e s e nd a r e q u e st t o i n f o @eir gr i d .c o m. Network data is a lso av ai lable on

t h e w e bsi t e i n e l e ct ro n i c f or m a t .

02the electricity transmission network2.1 overview of the electricity transmission network

2.2 existing connections with northern ireland

2.3 Plans for transmission system development

2.4 connection of new Generation stations

2.5 connection of new interface stations

2.6 detailed network information


2-1

2 THE ELECTRICITY TRANSMISSION NETWORK

2.1 OVERVIEW OF THE ELECTRICITY TRANSMISSION NETWORK

Th e na t i onal g r i d p l a ys a v i t a l r o le i n th e s uppl y o f e l ec t r ic i t y , pr ov i ding th e means t o

t r a n sp o rt pow e r f r o m th e gen e r at or s t o t he dem a n d c e n tres u s i ng a s y s t e m c o mp r is i ng

400 kV, 220 kV and 110 kV networks. The nat ional gr id is e lect r ica l ly connected to the

t ransmi ssion system of Nor thern I r e l and by means of one 275 kV double c i rcu i t connect ion

at Louth and two 110 kV connect ions at Let terkenny in Co. Donegal and Corrac lassy in Co.

Cav a n.

The 400 kV and 220 kV networks form the backbone of t h e gr i d . They h av e h i gh er c ap a c i t y

and lower losses than the 110 kV network. Th e 400 kV networ k provides a h igh capac i ty l ink

between Moneypoint g enerat ion s tat ion and G alway on the west coast and Dubl in on the

east . Th e 220 kV network compr ises a number of s ing le c i rcu i t loops around the country .

Typical ly la rge generat ion s tat ions (g reater than 100 MW) are connected to the 220 kV or

4 0 0 kV n et wo r k s .

The 110 kV 1 l i n e s , w hi ch c o n s t i t ut e d t h e e n t i r e t r a n s mi s si on s y s t e m pr i o r t o t h e 19 6 0 s ,

prov ide paral le l paths to the 220 kV system. I t i s the most ex tensive e lement o f the gr id ,

r e a ch i ng i nto e ve r y c o u nt y i n t h e R e pub l ic of I r e l and .

The t ransmi ssion system general ly compr ise s ov erh ead l i nes, ex c ept i n l i mit ed

c i rcumst ances, such as in the c i ty cent res of Dubl in and Cork, wher e underground cables

are used. Table 2 -1 presents the tota l lengths of overhead l ines 2 and cables at the d i f f erent

vo l tag e levels . Rev is i on o f ind iv idual l ine lengths ar e subj ect to conf i rmat ion fol lowing

complet ion of network development pro jects .

Tabl e 2-1 Tota l Length of Ex is t ing G r id C i r c ui t s a s a t J u l y 0 1 s t 2009

1 A n u m b e r o f r a d i a l 1 1 0 k V l i n e s a r o u n d t h e c o u n t r y a n d t h e 1 1 0 k V l i n e s a n d c a b l e s w i t h i n D u b l i n C i t y a r e c u r r e n t l y o p e r a t e d b y t h e D i s t r i b u t i o n S y s t e m O p e r a t o r ( D S O ) . T h e D S O l i c e n c e i s h e l d b y E S B N e t w o r k s . D e t a i l s o f t h e d i s t r i b u t i o n n e t w o r k i n D u b l i n a r e n o t i n c l u d e d i n t h i s T r a n s m i s s i o n F o r e c a s t S t a t e m e n t . 2 S o m e l i n e s m a y c o n t a i n s h o r t s e c t i o n s o f c a b l e .

Vol tage Level Tota l L i ne Leng ths (km) Tota l Cabl e Leng ths (km)

4 0 0 kV 43 9 0

2 7 5 k V 4 2 0

220 kV 1 ,725 104

110 kV 3 , 905 53


2-2

Transfor mers are requi red to l ink the d i f f er e nt v o l t a g e n e t wo r k s , p r ov i di n g p a t h s f or p o w er

t o f l ow f r om t h e h i g h e r t o t h e l o w e r v ol t age n e t w o r ks . T h e t o t al t r a n s f or m e r c a p a ci t y

between the d i f ferent vol tage l evel s is presented in Tabl e 2-2.

Tabl e 2-2 Tota l G r id T ransformer MVA Capaci ty as at Ju l y 01 s t 20 0 9 3

Vo l tage Level Capaci ty (MVA) Number of t ransformers

400/220 kV 2 ,550 5

275/220 kV 1 , 200 3

220/110 kV 8 ,989 47

React ive compensat ion dev ices are used to improve network vol tages in local a reas.

E x is t i n g r e ac t iv e d evi c es c o n n e ct e d t o th e g r id i n c l u d e sh u n t ca p ac i t o r s, s ta t i c v a r

compe ns ator s (SVCs) an d shun t r eactors . Tabl e 2 -3 show s the total amounts o f each type.

C a p a ci t or s a n d S V C s h e l p t o s u p po r t l oc al v ol t ag es i n are a s wh er e l o w v o l t ag e s m a y

o t h er wi s e occ u r . Sh u n t rea c t or s s upp r e s s v ol ta ge s i n ar e a s w h er e th e y w o u l d oth e rw i s e b e

too h igh, most l ikely dur ing per iods of low demand.

Tabl e 2-3 Tota l React ive Compensat ion as at Ju l y 01 s t 2009 4

Vol tage Level Type Capaci ty (Mvar ) Number of dev ic es

400 kV L ine Sh unt Reactor 160 2

220 kV Sh unt Reactor 100 1

1 1 0 k V S t a t i c V ar Com p e n s a t or 90 2

Swi tched Shunt C a p a ci t or

575 26

2.2 EXISTING CONNECTIONS WITH NORTHERN IRELAND

A s i l l u st ra t ed i n F i g ur e 2 - 1 , t h e n a t i o n al g r i d is c o n n e c t e d t o N o r th e r n I r e l a n d v ia t h r ee

275 5/220 kV t ransformer s in Louth st at ion, one 600 MVA uni t and two gang ed 6 3 0 0 M V A

uni ts , connected to a doubl e c i rcui t 275 kV l i ne running f rom Louth to Tandrag ee in Co.

Armagh. In addi t ion to the main 275/220 kV double c i rcu i t , there are two 110 kV

connect ions, one between Let terkenny in Co. Doneg al and St rabane in Co. Tyrone, and the

other between Corrac l assy in Co. Cavan and Enni ski l len in Co. Fermanagh. The purpose of

t h es e 1 1 0 k V c i rc u i t s i s to p r o v i d e sup p o rt t o e i th e r s ys t e m for c er t a i n con d i t i o n s o r i n t he

e v e n t o f a n u n e x p ec t ed c i r c ui t out a ge. P h ase s hi f t i ng t r a n s f or m e rs i n S tr a b a ne a n d

Ennisk i l l en are us ed to control the power f l ow under normal condi t ions.

3 T r a n s f o r m e r d e t a i l s a r e p r o v i d e d i n T a b l e s B - 6 , B - 7 a n d B - 8 i n A p p e n d i x B . 4 D e t a i l s o f e x i s t i n g r e a c t i v e c o m p e n s a t i o n d e v i c e s a r e p r o v i d e d i n T a b l e B - 1 0 i n A p p e n d i x B . 5 T h e t r a n s m i s s i o n s y s t e m i n N o r t h e r n I r e l a n d i s o p e r a t e d a t 2 7 5 k V a n d 1 1 0 k V . 6 P l a n t c o n n e c t e d i n p a r a l l e l t h r o u g h c o m m o n s w i t c h g e a r .


2-3

Whi le the des ign capaci ty o f ea ch of the 275/ 220 kV cross-border c i rcui ts is 600 MVA, the

a ctu al capaci ty o f th e c i r cui ts to accommodate t ransfers between th e tw o systems at any

t ime depends on the pr ev ai l ing system condi t ions on e i t h er s i de of th e bor der , i nc l udi ng

the abi l i ty to deal wi th system separat ion.

F ig u r e 2 - 1 Ex i s t i n g C r os s -B o r d er C i rc ui t s

2.3 PLANS FOR TRANSMISSION SYSTEM DEVELOPMENT

The Transmiss ion System Operat or (TSO) publ ished i ts T r a n s m i s si o n D e v el o p me n t P l a n

2008-2012 in J u l y 2 0 0 9 , f o l l ow i ng a p e r i o d of pub l ic c o ns u l t a t i o n . Th e r e p o rt d et ai l s t he

t r a n s mi s si on d e v e l op me n t p r oj e ct s t h at h av e be e n i n i t i ated b y t h e T S O i n a d d i t io n t o a

d i s c us s i o n of f ur t h er d ev e l o p m e nt s t h a t m a y a r i se i n th e p er io d o f th e pl an.

T h e d e v el o pme n t p l a n s i n c l u d e p r oje c t s r eq u ir ed t o f a c i l i ta t e d e m a n d g r o wt h a nd n e w

g enerat ion and demand connect ions in compl iance wi th the T ransmiss ion P lanning Cr i ter ia

(TPC) . The p lanned networ k developments pr esented in th is Tr ansmissi on Forecast

Statement (TFS) are based on thos e pro jec ts th at h av e b e e n s e l e ct e d a s op t i m u m s ol ut i o n s

to known network problems. A l l in format ion presented on network t ransf er capabi l i t ies and

o p p o rt u n i t i es i s c o n t i ng e n t o n t he c o m pl e t ion of th es e dev el op ment p r oj ect s i n th e

assumed t imeframe.

I t sh oul d be not ed th at t h e i nf or mat i on pr es ent ed h e r e i s a s n a p s h ot o f a n e v o l v i ng p l a n .

F u r th er i nv es t m e n t i s l ik e l y t o b e req u i re d before the end of the per iod of the pl an to

m a i n t ai n s t a n d a r d s i n a l l p ar t s o f t h e n etwork. Whi le the TSO is consider ing other

r e i n for ce m ent s , t he s e a r e n ot at t h e s ta g e of m a t ur i t y req u i re d f or i n c l u si o n in t h i s

s tatement . In addi t ion, the connect ion of new gen e r a t i o n or l ar ge p oi n t d e m a n d s ar e l i k el y

t o h av e a s t ep ch ang e o n n et w o rk p er f or m a n c e l eadi n g t o f ur th e r d ev e l o p m e n t

Louth

Tandragee

Letterkenny

Strabane

Northern Ireland

Republic of Ireland

Enniskillen

275kV Lines

110kV Lines

Corraclassy

Ballycronanmore

Moyle interconnector to Scotland

Louth

Tandragee

Letterkenny

Strabane

Northern Ireland

Republic of Ireland

Enniskillen

275kV Lines

110kV Lines

Corraclassy

Ballycronanmore

Moyle interconnector to Scotland


2-4

requi rements . The solut ions are l ike ly to be a c ombi nat i on of r obust s t rateg ic dev elopment s

a n d sh o rt t er m r e i n for ceme n t s t o mai n t ai n f l ex i bi l i t y i n t h e sys t e m .

T h e f o l l o w i n g i s a n o v er v i e w o f t h e ma j o r 400 kV and 220 kV network developments pl anned

f o r t h e s y s tem a t th e b egi n n i ng o f J u l y 2 0 0 9 , w h en d a t a w a s f r o z e n i n o r der t o f a c i l i t at e th e

complet ion of the TFS. The Transmiss ion Development P lan 2008-2012 inc l udes deta i l s o f

t h es e a n d o f s i g ni f i c a nt 1 1 0 k V r e i nfor c e m e nt pro jects p l anned for the system. The pl anned

developments are i l lust rated on a map and on the schemat ic network d iagrams in

Appendix A . New generat ion connect ions and new t ransmissi on inter face s tat ions are

descr ibed in Sect ions 2 .4 and 2 .5 respect ivel y .

2.3.1 Lodgewood 220 kV Development

Lodgewood 220 kV st at ion in Co. Wexfor d wi l l be connected into the ex ist ing Arklow-Great

Is l a nd 220 kV l i n e an d l i n ked to Cr ane 110 kV stat ion. Th is re in forcement development is

requi red to ensure that adequate in f r ast ruct ure is i n p la c e to m e e t t he i nc r e a si ng e lec t r i c i t y

demand in the area and reduce the r isk of loss o f supply a t wint er peak and dur ing

m a i n t e n a nc e o u t ag es . Thi s p r oj e ct i s d u e f or c o mp l et i o n i n 2 01 0 .

2.3.2 Aghada-Raffeen 220 kV Circuit

T h e p l a n n e d n e w 2 2 0 k V c i r cu i t f r o m A g h a da t o R a f f e e n i n Co. C o r k w i l l b e p a r t s u bma r i n e

c a b l e, p ar t u n d e r gr o u n d c a b l e a n d p a r t ov er h ea d l i n e. I t is e x p ec t e d to b e c o m p l et e d i n

2010.

2.3.3 Flagford-Srananagh 220 kV Development

Srananag h 220 kV st at ion, east of Sl igo town, wi l l be connected to the 220 kV networ k by

an over head l ine f r om F lagford, near Carr ick-on-Shannon, thus extending the 220 kV

network in to the nor th-west . A number o f 110 kV l ines wi l l be connected into the new

stat ion, maki ng Sr ananag h a new hub for power f l o w s i n t o t h e n o rth -w e s t . Th e F la g f or d -

Srananag h 220/110 kV pr o jec t is needed to re i nf o r c e th e n et w o rk i n t h is a re a of g ro w i ng

demand, and to reduce the r isk o f loss o f supply a t wi nter peak and dur ing maintenance

outages. The 110 kV e lements o f th is proj ect were completed in 2009 . At the t ime of the

data f r eeze, i t was assumed that the 220 kV e lements o f the pr oj ect would be due for

c omplet i on in 2011 .

2.3.4 Glanagow-Raffeen 220 kV Circuit

The p lanned new 220 kV c i rcu i t f rom Gl anag ow to Ra f f een i n Co. Cor k w i l l be p a r t s ubma r i ne

c a b l e, p a rt und e r gr o u n d c a b l e . I t i s ex p e ct e d t o be c o m pl et e d i n 2 0 1 1 .


2-5

2.3.5 400 kV line to Northern Ireland

A new 400 kV l ine between the na t ional gr id and Northern I re l and is cur rent ly be ing

prog ressed by the TSO and Nor thern I re land E lect r ic i ty (N IE ) . The l ine wi l l connect in to a

new 400/220 kV s tat ion, probably located in Co . Cavan, prov is ional l y re f er r ed t o as t h e

Mid- C avan st at i on e lsewh er e i n th i s T FS.

In the ev e nt o f a loss of the ex i st i ng 275 kV doubl e c i rc ui t c onnec t i ng th e nat i onal g r i d t o

Nor the rn I r e l an d , the p re- fau l t t r an sf ers woul d be d i rected ac ross the Let terkenny-St rabane

and Corrac lassy-Enniski l len 110 kV c ross-border c i rcu i ts . In th is inst ance, to guar d ag ai nst

d a m a g e t o th e s e l i n e s, p r o t ec t i o n eq u i p m e nt wi l l sw i t ch o ut th e 1 1 0 k V c i r cu i t s r e s ul t i ng i n

separat ion of the two syst ems.

System separat ion, depending on the pre-separat ion f low on the Louth-Tandrag ee 275 kV

d o u b l e c i r c ui t , ma y r e s ul t i n a g e n er at i o n s ur plus on one system and a def ic i t on the other .

The s ys te m wi th a supply d ef i c i t may be requ i red to d isconnect demand customers. The

s y s t e m wit h t h e s u p pl y s u r pl u s m a y h av e d i f f i cu l t y s t a bi l i s i n g t h e s y s t e m f r e q u e ncy . T h e

i m p a ct o f pot e n t i a l s y st e m s e p ar a t i o n o n e a c h s y s t e m c a n r e s u l t i n con s t r ai n ts o n t he

amount of power that can be t rans fer red between the two systems.

The new c i rcu i t wi l l pr ov ide an a l ternat ive h igh capaci ty path for power f lows in the ev ent of

t h e l oss of th e ex i s t i ng c i rc ui t s . I t wi l l th erefor e overcome the system separat ion issue and

a l l e v i at e c on s t r ai n ts o n p o w e r t ra n sf e r s b et w een t h e t w o s ys t e m s . Th e p r o j e c t i s e x p e c t e d

t o b e c o m pl et e d i n 2 0 1 2 .

2.3.6 400 kV line from Woodland to Mid-Cavan

A 400 kV l ine is p l anned f rom the ex is t ing Woodland 400 kV s tat ion nor thwar ds to the

p l anned Mid-Cavan 400/220 kV s tat ion. Tog eth er wi th the pl anned 400 kV l ine f rom Mid-

C a v a n t o N ort h er n I r e l a nd t h i s wi l l f ur th e r st ren gth e n th e l i n k b e t w e e n t h e t w o t r a n s mis s i o n

systems. I t i s ex pect ed to be completed in the second hal f of 2012.

2.3.7 East-West Interconnector

I n J u l y 2 0 0 6, t h e Dep ar tm e n t o f C o m m u n i c at i o n s, M a r i n e a nd N a t u r al R es o u r c es r e que s t e d

that th e Commission for Energy Regulat i on (CER) ar rang e a compet i t ion to secure the

c onstr uc t i on of a 500 MW East -W est i n t er c onnect or bet w een I r e l a nd a nd G r ea t Br i t a in. Th e

C E R w a s a l so r e q u es t e d t o i n st r uc t th e T S O t o c ar r y o ut th e tec h ni c al w o rk o f s el ec t i on o f a

s u b - s e a r o u t e a n d o t h e r s i t es f o r t h e c o n s t r uc t ion o f the in terconnect or and necessary gr id

r e i n for ce m ent w or k s .

In Ju ly 2007 the CER approved the choice o f Woodland as the connect ion point on the I r ish

s y s t e m f or t h e i n t er c o nn e c t o r , a s rec o m m e n d ed by t h e TSO . Fol l ow i ng th e s i g ning of a


2-6

c o n n e c t i o n ag r e e me n t w i t h Na t i o n al G r i d U K i n Sep t e m b er 2 00 7 , D ee s ide i n N o rt h W ales h as


t o b e i n p l a ce b y 2 0 1 2 .

2.3.8 Finnstown 220 kV Development

F innstown 220 kV s tat ion, in west County Dub l i n , w i l l be c o n n e c t ed i n t o th e ex i st i ng

Inchicor e-Maynooth No. 1 and No. 2 220 kV l ines. A number o f the ex is t ing 110 kV l ines in

the ar ea wi l l be connected to the new F i nnstown st at ion, ensur ing that adeq uate

i n f ra s tr u ct u re i s i n p l a c e t o m e e t th e i n c r e as i ng e l e ct r i c i t y dem a n d i n the West Dubl in area

and reducing the r isk o f loss of supply a t wint er peak and dur ing maintenance outages. This

p r o j e c t i s d ue f or c o m pl et i o n i n 2 0 13 .

2.3.9 Balgriffin 220 kV Development

B al gr i f f i n 2 20 k V st a t i o n, i n n or th Cou n t y D u bl in , w i l l b e c on n e c t e d t o th e 2 2 0 k V net w or k

by an underground cable f rom F inglas . A number o f the ex ist ing 110 kV l ines in the ar ea wi l l

b e c o n n e c t ed t o th e n e w B al gr i f f i n s ta t i o n, e n s u r in g th a t a d e qu a t e i nf r as truc t u re i s i n p l ac e

t o m e e t th e i n c r ea si n g e l e ct r i c i t y d em a n d i n t h e N o r th Ea s t D u b l i n ar e a a n d r e d uc i ng the

r i s k o f l o s s o f s u p pl y at w i n t e r p ea k a n d d u r i ng m a i n t e n a nc e o u t ag e s . Thi s pr o j ec t i s d u e

f o r c o m pl et io n i n 2 0 13 .

2.3.10 Kilpaddoge 220 kV Development

K i lpaddoge 220 kV s tat ion, in nor th Co. Kerr y , w i l l b e c o n n e c t e d i n t o th e e x i st i ng

C l ashavoon-Tarber t and K i l l ona n-Tarber t 220 kV l ines. A number o f 110 kV l ines wi l l be

connected into the new stat ion, making K i l p a dd o g e a n e w h u b f o r p ow e r f l o ws i n t o t h e

south-west . K i lpaddoge 220/110 kV pro jec t is needed to accommodate the p lanned

g e n e ra t i o n in t h e s o ut h-w e s t a n d th e r ef u r bi s hme n t o f th e e x i st i ng T ar b e rt 2 2 0 k V . T h is

p r o j e c t i s d ue f or c o m pl et i o n i n 2 0 13 .

2.3.11 Moneypoint-Kilpaddoge 220 kV Circuit

A p lanned new submar ine cable across the Shannon estuary f rom Moneyp oint in Co. C l are to

K i l p a d d og e in n o r t h C o . K e r r y wi l l c re a t e a n e c e ss a r y n e w p ath f o r p o wer o u t o f t he Dub l i n -

M o n e y p oi n t g r o up o f gener a t or s i n t o t h e sou th - wes t a n d a pat h f or p ow e r o u t o f th e sou t h -

w e s t t o th e 4 0 0 kV n et wo r k . I t i s ex pec t e d t o b e c o m p let e d in 2 0 1 3 .

2.3.12 Ballyvouskill 220 kV Development

Bal l yvouski l l 220 kV s tat ion wi l l be l ooped into the ex is t ing C lashavoon-Tarber t 220 kV

l i ne. The s ta t i o n wi l l be l i nk e d to the ex ist ing Garrow 110 kV s tat ion by two new 110 kV


2-7

o v e r h e a d l i nes . B al l y v o us k i l l 2 2 0 / 1 10 k V p r oject is needed to accommodate the pl anned

g e n e ra t i o n in th e s o u th -w e s t . T hi s pro j e ct i s d u e f o r c o m pl et io n i n 2 0 1 4 .

2.3.13 Knockanure 220 kV Development

Knockanure 220 kV s tat ion wi l l be looped into the ex is t ing Clashavoon-Tarber t 220 kV l ine.

The s tat ion wi l l be l ooped into the ex is t i ng Tr ien-Tarber t 110 kV c i rcui t and the p lanned

Tr ien-Athea 110 kV c i rcui t . Knockanure 220/110 kV proj ec t is needed to accommodate the

p l a n n e d gener a t i o n i n the s o ut h - wes t . T hi s p r oj ect i s d u e f o r com p l et i o n i n 2 0 1 4 .

2.3.14 Kishkeam 220 kV Development

K i sh k e a m 220 k V s t at i on w i l l b e l oo p e d i n t o t he ex is t ing Cl ashavoon-Tarber t 220 kV l i ne.

The s tat ion wi l l be l i nked to the ex is t ing Glenlara 110 kV s tat ion by a new 110 kV overhead

l ine . K i sh keam 220/110 kV pro ject is needed to a c c o m m o d at e t h e pl a n n e d g e n e r at i o n i n t h e

s o u t h -w e st . T h i s pr o j ec t i s d u e f o r c om p l et i o n i n 2 0 1 4 .

2.3.15 400 kV station near Portlaoise

A new 400/110 kV s tat ion in the v ic in i ty o f Por t laoi se, Co. Laois, is p l anned to pr ov ide

v o l t ag e suppor t i n t h e K i lkenny area and t o r e in force the networ k in the K i ldar e , Laois and

K i lkenny areas. The s tat ion, prov is ional ly re fer r ed t o a s t h e La o i s s t a t i o n e l s ew h er e i n t h i s

T F S , w i l l b e c o n n e c t e d int o th e e x i st i ng M oneypoint -Dunstow n 400 kV l ine and the p l anned

Por t lao ise-At hy 110 kV l ine 7. The s tat ion wi l l be l inked to K i l kenny 110 kV s tat ion by a new

110 kV overhead l ine . Th is pr o jec t is due for complet ion in 2014.

2.4 CONNECTION OF NEW GENERATION STATIONS

Sect ion 4 .1 in Chapter 4 descr ibes the future g e n e r at o rs t h at h av e s i g n e d c o nne c t io n

ag reements . Table 2-4 shows the connect i o n m et h o d f or th es e g e n e ra t ors .

Tabl e 2-4 P lanned Connect ion Meth ods o f F ut u r e G e n e rat or s

G enerat or P lanned Connect ion Method

Ag hada CCGT Connected to a new Long poi nt 220 kV s ta t i o n , i ts e l f t a i l - c o nn e c t e d i nt o Aghada 220 kV st at ion

Athea New At hea 110 kV s tat ion ta i l -connected into Tr ien 110 kV s tat ion

A t h ea W i n d F a r m ( E x t e ns i o n )

Connected into the pl anned Athea 110 kV s tat ion

7 T h e n e w A t h y 1 1 0 k V s t a t i o n i s e x p e c t e d t o b e c o m m i s s i o n e d b y t h e e n d o f 2 0 1 0 a n d i t w i l l b e c o n n e c t e d i n t o t h e e x i s t i n g C a r l o w – P o r t l a o i s e 1 1 0 k V l i n e .


2-8

Tabl e 2-4 P lanned Connect ion Methods of F ut u r e G e n e ra t or s (Co n t i n u e d )

G enerat or P lanned Connect ion Method

B al la k el l y Connec t e d to a new B al lak e l l y 220 kV s ta t i o n , i ts e l f t a i l - c o nn e c t e d i nt o Louth 220 kV s tat ion

B indoo Wind Farm (Extensi on)

C o n n e c t e d int o t h e ex i st i n g R a tr u s san 1 1 0 kV st at i o n

B o gg er ag h N e w B og g eragh 1 1 0 k V st a t i o n t a i l -co n n e c t e d i nto C l ashav o on 2 2 0 k V s tat ion

Bool t i ag h Wind Farm (Extensi on)

C o n n e c t e d int o t h e ex i st i n g B oo l t ia gh 1 1 0 k V st a t i o n

Cast ledockr i l l New Cast ledockr i l l 110 kV s tat ion ta i l -connected into Lodgewood 220 kV s tat ion

C loghboola Connected to a new Knoc knagashel 1 1 0 k V s ta t i on ; i ts e l f t a i le d i nt o T r ien 110 kV s tat ion

D roma da N ew Dr omada 110 kV s tat ion ta i l -connected into Athea 110 kV st at ion

E d e n d e rr y C o n n e c t e d int o t h e ex i st i n g C u sh a l i ng 1 10 k V st a t i o n

G ar v agh N e w G ar va gh 1 1 0 k V st a t i o n t a i l - co n n e c t e d i nt o Cor d e rr y 1 10 k V st a t i o n

Glanlee Wind Farm (Extensi on)

C o n n e c t e d int o t h e ex i st i n g G la n l e e 1 1 0 k V s ta t i on

Ke e l derry New Keeld er r y 110 kV st at ion ta i l -connected into Derrybr ien 110 kV s tat i on

Knockacummer New Knoc kacummer 110 kV st at ion ta i l -c onnected into Glenlara 110 kV s tat ion

Moneypoi nt Wind F a r m

Connected into ex is t ing Moneypoi nt s tat ion at 110 kV

Mul reavy New Mulreavy 110 kV s tat ion ta i l -connected into Cathal een's Fa l l 110 kV s tat ion

N o r e P ow e r C o n n e c t e d to a new N o r e 1 1 0 kV s tat ion, i tse l f ta i l -connected into K i lkenny 110 kV s tat ion

W hi t eg at e C o n n e c t e d to a new Gl a na g o w 2 2 0 k V s ta t i o n , i t se l f ta i l - c o n nec t e d i nt o Aghada 220 kV st at ion

S i n c e t h e d at a f r e e z e a t t h e b eg i n n i ng o f J u l y 2009, connect ion ag reeme n ts w e r e s ig n ed f o r

three new convent ional g enerat ion p l ants , Cui l leen 9 8.4 MW O CG T p lant a t At hl one, Co .

Westmeath, Sui r 98 MW OCGT p lant a t Cahi r , Co. T ipperary and Caulstown 58 MW OCGT

Peaking P lant a t Cauls town, Co. Louth as wel l as one 70 MW pumped storag e plant a t

Knocknagreenan, Co. Cork . Table 2 -5 shows the p l anned shal l ow connect ion methods for

t h es e pl a nt s.


2-9

Ta b le 2 - 5 P l an n ed Con n ec t ion M eth ods o f Future Wind Farms Agreed Af ter th e Data F reeze

W i n d f ar m P lanned Connect ion Method

Cui l leen Connected to a new Cui l leen 110 kV st at ion, i tsel f ta i l -connected into Ath lone 110 kV st at ion

Sui r Connected to a new Sui r 110 kV s tat io n, i tse l f ta i l -connected into Cahi r 110 kV s tat ion

C a u l st o w n C o n n e c t e d to a new C a u ls t o w n 1 1 0 kV s ta t i o n , i ts e l f con n e c te d i nt o th e ex is t ing P l at in -Corduf f 110 kV l ine

Knocknagreenan Connected to a new Knoc knagreenan 110 kV s tat ion, i tsel f ta i l -c o n n e c t e d i nt o C ar r i ga d roh i d 1 1 0 k V s t a t i o n

2.5 CONNECTION OF NEW INTERFACE STATIONS

F o r t h e p er io d c ov e r e d b y t h i s s t ate m e n t , T a ble 2 -6 l is ts the p l anned new 110 kV s tat ions

c o n n e c t i n g t h e d i st r i b ut i o n s y s t e m o r di r ec t l y- c o n n e c t e d c u s t o m er s to t h e g r i d . T h e s e

s tat ions are inc l uded in the appropr iate netw or k models ac cor di ng t o th ei r ex pect ed

connect ion date . Deta i ls o f the connect ions and dates are g iven in Sect ion B.2 in

Appendix B .

Tabl e 2-6 P lanned 110 kV Stat ions

Stat ion Code N e a r e st M ain T o w n

o r L oa d C e ntr e

County

Adamstow n ADM Lucan Dubl in

Bal l ycummin BCM Raheen L imer ick

B al l yr ag ge t B G T B al l yragget K i lkenny

B a n og e B OG G o rey W e x fo r d

B r ac kl one B RA P ort ar l i ngt on La oi s

Bunbeg BU N Na Doi r i Beag a Dun na nGal l

Car rowbeg CBG Westport Mayo

Cherrywood CHE Loughl instown Dubl in

H a rt n e tt 's Cro s s H T S M a cr o o m C o r k

K i l ma h u d K U D C l o n d al k i n D u b l i n

Nenagh NEN Nenagh T ipperary

Ral apanne RAL Ral apanne Kerry

Sal th i l l SAL Sal th i l l G al w ay

Screeb SCR Camus Iochtar Gal l imh

Singl a nd SNG G arryowen L imer ick


2-10

2.6 DETAILED NETWORK INFORMATION

F igure A-1 in Appendix A presents a geog raphica l m a p of the g r i d at the b e g i nni ng o f J u l y

2 0 0 9 . Th is is a l s o av a i l ab l e i n A 3 f orma t i n Ap p en d i x I .

T h e e l e ct r i ca l c h ar ac t er i s t i cs a n d ca p a ci t y r at in g s o f t h e ex i st i ng n et wo r k ar e i n c lu d e d i n

t h e f o l l o wi ng t a bl e s i n Sec t i o n B . 1 o f A p p e n di x B .

Tables B-2 to B-5 l is t the e l ect r ica l ch aract e r i s t i cs o f t h e e x i st i ng ov e r h e a d l i nes a n d

u n d e r gr o u n d c a bl e s a t the d i f f er e n t vo l ta g e l e v els . Th e rat i ngs are sh own in MVA for winter

a nd f or s ummer r e fer en ce temper at ure condi t ions, 5°C and 25°C respect ive ly .

T a b l e s B - 6 to B - 8 l i s t d a t a f o r e ac h e x i st i ng t rans m i s si o n t ra n s f o r m er . T h e d a t a i n c lu d e s

impedanc e va lues, nameplat e ra t ings and tap rang es. Th e vol tag e tapping rang e for each

t r a n sf o r m er i s g iv e n a s th e p er c e nt ag e d evi a t i o n f r o m th e n om i n a l v ol t age r at i o a t the t w o

ext reme tap posi t ions.

T a b l e B - 9 l i s t s det ai l s o f t h e ph a s e shi f t i ng t r a nsformer a t Carr ickmines 220 kV s tat ion.

Tabl e B -10 inc l udes t h e M v ar c apaci ty data f or ex i s t i ng r eact iv e c ompensat i on dev i ces.

F igure A-2 in Appendix A presents a geographica l map of the gr id as forecast in 2016,

inc l uding the p lanned developments. The sc hemat ic network d iag rams in Appendix A show

snapshots of the ex ist ing gr id and p lanned developments at the end of 2009, 2010, 2013

and 2016. The di ag rams indi cate s tat ions, c i rcu i ts , t ransformers, generat ion, react ive

d e v i c e s a n d p h a s e shi f t i n g t r a ns f o r me r s .

T h e e l e ct r i ca l c h a r ac t er i s t i cs a n d ca p a ci t y r at i n g s of p l a nn e d n e t wo r k d e v el o p ment s ar e

i n c l u d e d i n th e f o l l ow i ng t a bl e s i n S ec t ion B . 2 of A p p e n d ix B .

Tabl es B-11 to B-16 conta in data for new l ines and cables and p lanned ch anges to ex ist ing

l ine and ca bl e data on an annual bas is . These tables inc lude a co lumn to indicate whether

e a c h l i s t e d i t e m o f p la n t i s b e i ng a d d e d, amended or de leted. Changes re la t ing to a

par t icular development pro ject ar e grouped toge ther and headed by a pro ject descr ipt ion

w hi ch i nc l udes th e Capi ta l Pr o jec t (CP ) number .

Tabl es B-17 to B-22 l is t the deta i l s o f the p lanned network t ransformers .

T a b l e s B - 23 t o B - 2 4 i nc l u d e th e Mv a r c a pa ci t y d a t a f o r p la n n e d r e ac t i v e c o m p e nsa t i o n

dev ices .

E lect r ica l ch aracter is t ics o f fu ture t ransmi s si o n p l a n t or c h a ng e s t o t h e e l ect r i c al

char acter ist ics br ought about by p lanned developments are pr el iminary . E l ec t r ica l

c h ar a ct er i st ic s w i l l be rev i ew ed wh en the p lant is commissioned.

03demand3.1 forecasts of transmission Peaks

3.2 comparison with Previous demand forecast

3.3 forecast demand at transmission interface stations

3.4 demand Profiles


3-1

3 DEMAND

The f low of power on the gr id is determined large l y b y t h e g en e r a t i o n f eedi n g i n t o i t a n d t he

de mand tha t i s dr awn f r om i t . Th i s chapter deal s wi th forecast s o f the tota l peak demand on

the t rans miss i on n etwor k, an d of d emand at indiv idual t ransmiss ion-connected s tat ions.

The Generat ion Adequacy Report 2010-2016 (G AR) , publ ished by the Tr ansmiss ion System

Operator (TSO) in November 2009, conta ins forecast s o f fu ture energy consumpt ion and

demand for the seven-year per iod to 2016.

3.1 FORECASTS OF TRANSMISSION PEAKS

Table 3 -1 presents the forecasts o f t ransmiss ion demand for the seven years 2010 to 2016,

as they were expected to be publ ished in the GAR. I t sh ould be noted that these forecasts

w e r e t h e b es t a va i l a bl e p r o j ec t i o n s d u r i ng th e p r e p ar at i o n o f t h i s st ate m e n t . U l t im a t el y ,

t h e f i gur es publ is h ed i n th e G AR 20 10-20 16 ma y di f f er s l igh t l y .

W hi l e i t is d i f f i c ul t t o a c c ur a t el y pr e d ic t a p e ak d e m a n d f ig u r e f or a par t i c ul ar y e a r , th e

forecasts in Table 3 -1 may be taken as indicat ive o f a general t rend in demand growth.

Three demand values are pres ented for each year : the wi nter peak, the summer peak and

t h e s u m m er v al l e y.

Table 3 -1 T ransmissi on Demand Forecast , MW

Year Summer P eak Summer Val ley Winter Peak

2010 3 ,709 1 ,669 4,63 6

2011 3 ,780 1 ,701 4 ,725

2012 3 ,878 1 ,745 4 ,848

2013 3 ,953 1 ,779 4 ,941

2014 4,029 1 ,813 5 ,037

2015 4 ,107 1 ,848 5 ,134

2016 4,186 1 ,884 5 ,233

The wint er peak f igures represent the expected annual peak demands that are forecast to

o c c u r i n t he O c t o b er to F e b r u a r y w i n t er p e r i od o f e a c h yea r e . g . , t he 2 0 1 0 f o r ec a s t o f

4 ,63 6 MW is the maximum demand pro jec ted to occur in winter 2010/11 . These peak

forecasts take account o f the in f l uence o f demand-s ide management (DSM ) schemes, such

as the TSO’s wi nter peak demand reduct ion scheme (WP DRS) . In winter 2008/09, DSM

accounted for approx imatel y 138 MW of a reduct ion to the peak demand. Th is amount o f

D S M i s as s um e d t o c o nt inu e o ve r th e n e xt e ig ht yea r s .

T h e s u m m e r p e a k r e f er s t o t h e av era g e p e ak v al u e b e t w e e n M a r ch a n d S e p t e m b er . T h i s i s

typ ical ly 20% lower than the wi nter peak. Whi le t h e o ve r al l gr i d p o w er f l o w m a y be l o w e r i n

s u m m e r th an i n w i nt e r , t h i s m a y n ot b e t h e c a s e f o r f l ow s on a l l c i rc u i ts . I n a d d i t ion, t h e


3-2

c a p a ci t y o f o v e r h e a d l i nes i s l ow e r b e c a u s e of h igher ambient temperat ures, wh i le network

m a i n t e n a nc e, n o r m al l y c a rr i e d o u t i n th e M ar ch t o S ep t em b e r p er io d, c a n w e ake n th e

network, fur ther reduci ng i ts capabi l i ty to t ransport power .

T h e a n n u a l m i n i m u m i s r e f er r e d t o a s t h e s u mme r v al l e y in t h i s T F S . S u m m e r v al l e y c a s e s

e x a m i n e t h e i m p a ct of l e s s d e ma n d a n d l ess generat ion d ispatched. Th is min imum

condi t ion is o f par t icular in terest when assessing the capabi l i ty to connect new generat ion.

Wi th l oca l demand at a min imum, the connect ing g e n er a tor m u s t e x p or t m o r e o f i t s p o w e r

a cross th e gr i d than at p eak t i mes. The forecasts o f summer val ley demands in Table 3 -1

assume a f i gure o f 36% of the annual maximum demand, which is consistent wi th h is tor ical

summer va l ley demand da ta .

3.1.1 Peak Out-turn for Winter 2008/09

The peak exported demand in wint er 2008/09 was 4, 873 MW. This f igure is 269 MW lower

tha n the t r an smi ssi on p eak for ecast for wi nter 2008/09 of 5 ,142 MW pr esented i n

T ransmiss ion Forecast St atement 2008-2014 . At the t ime of peak the product ion f r om wind

g enerat ion was 222 MW. The h igh peak f igure indi cates the d i f f icu l ty in accurate l y

predic t ing the maximum demand in a par t icul ar year . Peak demands may be h igher or lower

tha n f orecast d epen d i ng on fac tor s such as weat her condi t ions and customer behaviour .

T h e T SO w i l l c o n t i n u e t o m o n i t or fut ur e pea k s a n d a dj u s t i t s f or e c a st s a cc or d i ng l y.

3.2 COMPARISON WITH PREVIOUS DEMAND FORECAST

Tabl e 3 -2 compares the winter peak t ransmi ss ion demand forecasts in th i s TFS wi th t h ose

g iv e n i n Tr ansmi ssi on For ec ast St atement 2008-2014 . T h e c ur r e n t d e m a nd f o r e ca s ts r e f l e ct

an aver ag e increase in winter peak demand of 2.0% over the per iod 2010 to 2016. Th is is

l o w er t h a n l a s t y e ar ’ s for e c as t av era g e a n n ual increase to 2014. Table 3 -2 presents the

d i f f er e n ce s b e t w e e n t h e p e a k s f or e ca s t i n t h e pr ev ious TFS and the cu rrent f orec a sts . Th e

new peaks forecast are lower than last year ’s forecasts as a consequence of the decrease in

t h e ex p e ct e d r at e o f d e ma n d gr o wth .

Table 3 -2 Compar ison of Peak Dema nd Forecast wi th Prev ious TFS, MW

2010 2011 2012 2013 2014 2015 2016

TFS 2010-2016 4,63 6 4,725 4 ,84 8 4,941 5 ,03 7 5 ,13 4 5 ,233

TFS 2008-2014 5 ,442 5 ,600 5 ,762 5 ,930 6,102 N/A N/A

Di f ference -806 -875 -914 -989 -1 ,065 N/A N/A

3.3 FORECAST DEMAND AT TRANSMISSION INTERFACE STATIONS

Transmiss ion in ter face s tat ions ar e the poi nt s o f c o n n e ct i o n b e tw e e n t h e t r a ns mi s si o n

system and the d is t r ibut ion sys t em, o r d i r e ct l y - c o n n e ct e d c u s t o m e r s . T h e s e a r e m o s t l y


3-3

110 kV s tat ions. In Dubl in c i ty , where the Dist r ibut ion System Oper ator (DSO) operat es the

1 1 0 k V n e two r k , th e i n ter f a ce i s u s u al l y at 2 2 0 k V s ta t i o n s .

Appendix C l is ts the forecast demands at each t r a n s m i ss i on i n t er f ace s tat ion at t ime of

winter peak, summer peak an d summer val ley for a l l year s f rom 2010 to 2016. Demand

pro ject ions at indi v idual t ransmiss ion s tat ions are developed f rom the system demand

forecasts on a top-down basis . Th e forecast ing p r o c es s i n c lu d e s r e g ul ar m o n i t or i ng a n d

rev iew of t rends in cons umpt ion in a l l par ts o f th e cou n t r y. T h e a l l oc at i o n o f t he s y s t e m

demand forecast to each s tat ion is based pro-rata on an up- to-date measurement o f ac tual

p e a k d e m a nd a t e a c h sta t i o n . A cc o unt i s t aken of p lanned t ransfer s o f demand between

s tat ions as agreed wi th the DSO. In th is way, c h a ng e s i n t h e g e o - divers i ty o f e lect r ic i ty

consumpt ion are capt ured. Th is process pr ov ides a s tat ion demand forecast and by

e x t e n si o n a r e gi o n al d em a n d f or e c as t f o r th e sho r t t o m e di um t er m .

T h e s y s t e m -w i d e d e m a nd f o r e c as t s, p r e s e n t ed in Table 3 -1 , inc l ude t ransmissi on losses

w h er e a s t h e i n d i v i d ua l s t a t i o n d e ma n d f o r ecast s do not . T ransmiss ion losses therefor e

a c c o u nt f or t h e d i f f er e nc e b e tw e e n t h e s y st e m -w i d e d e m a nd f o rec a st s a n d th e s u m o f t he

f o r e ca s ts at e a c h i n t er f ac e st at i o n i n A p p e n di x C .

Demand forecasts for the smal l number o f d i rect ly -connected customer s ar e th e curr ent best

est imates of requi rements . In some cases, the est imates may be less than contracted

M a xi m u m Imp o r t C ap ac i t y ( M I C ) va l u e s, b u t a r e ch o s e n t o g i ve a bet t er p ro j ect i o n o f

expect ed demand on a system-wide bas is . However , wh en analysing the capa ci ty for new

de mand in a p ar t i cular a r ea, the M IC values o f l o c al d i rec t l y -c o nnect e d c u s to mer s a r e

assumed to ensure that the contracted MIC is reserved.

A l though demand-s ide management schemes ar e expected to reduce some industr ies '

demands over wint er peak hours , the i r normal dema nd l eve l s ar e i nc luded i n th e w i nt er

peak demand forecasts shown in Table C-1 in Appendix C and are used in the power f low

d iag rams in Appendix J , as they ar e more indicat ive o f genera l power f l ow s.

3.4 DEMAND PROFILES

E l e ct r i c i t y us a g e fo l l ows s o m e g e ner al l y ac c ept ed pat terns. For example, annual peak

demand occurs between 17 .00 and 1 9 .00 on wi n t e r w e e k d a y e v e n i ng s, w h i l e m i ni m um u s a g e

occurs dur ing summer weekend night - t ime hours . F i g u r e 3 - 1 sh ow s t h e p r o f i l e for t h e

weekly peaks across the year for 2008.

F igure 3 -2 presents four da i ly demand p r of i l es t h at i ndi c ate h ow el ectr i c i t y us a ge v a r i es

throughout the day. The demand prof i les are f o r th e d a y o n wh ic h t h e a n nua l p e ak o c cur r ed

i n 2 0 0 8 a s w e l l a s p r o f i l es f or t y pic a l s ummer and winter weekdays and for the min imum

d e m a n d d a y. T h e p r o f i l e s , wi t h dem a n d l ev el s r a ng i ng f r om a p p r o x i ma t el y 1 , 8 2 0 M W t o


3-4

4 , 8 73 M W , i n d i c at e t h a t t h e p o w er s ys t e m d ea l s w i th a wi d e v a r i at i o n i n d e m a n d th r ou g h o ut

t h e y e ar . E ve n wi th i n the d a y d e m a nd va r i a t i o n s a r e s u b s ta n t i a l .

F igure 3 -2 i l lust rates that on the wi nter peak day t h e peak demand is a l most t wi c e th e

minimum demand on that day, a var ia t ion of ov e r 2 , 5 13 MW . A n u m b e r o f p o i nt s o n t h i s

d i ag r a m, t h e w i n t er p e a k ( W P ) , t yp i c al s u m m e r peak (SP) and summer val ley (SV) demands,

a r e e x a mi n ed i n th e a n aly s e s u n d er tak e n f or t h i s T F S .

3400

3600

3800

4000

4200

4400

4600

4800

5000

0 5 10 15 20 25 30 35 40 45 50 55

Week

Pe

ak

De

ma

nd

(M

W)

F igure 3 -1 Weekly Peak Values for Year 2008

1000

1500

2000

2500

3000

3500

4000

4500

5000

5500

0 6 12 18 24

Hour

Exp

ort

ed

De

ma

nd

(M

W)

Winter Peak Typical Winter Typical Summer Summer Minimum

F ig ur e 3 -2 Dai l y D emand Pr of i l es f or Year 2008

W P

S P

S V

W P

S P

S V

04Generation4.1 existing and Planned Grid-connected Generation

4.2 Planned retirement/divestiture of Generation Plant

4.3 embedded Generation

4.4 wind Generation


4-1

4 GENERATION

T h i s ch a pt e r g i v es i n f o r m a t i o n a b o ut ex i st i ng generat ion capaci ty and pr o jec t ions for the

s e v e n y e ar s t o 2 0 1 6 . A l l g e n er a t i on c a p a c i t y a n d d i s pa t c h f i g ur e s i n t h i s T r a nsmi s si o n

Forecast Stat ement (TFS) are expr essed in ex por te d o r n et t e rms i . e . , g e ner a t i o n u ni t o u t p u t

less the uni t ’s own auxi l ia ry load.

On th e 01 s t o f J u l y 200 9 , w h en dat a wa s f r oz en i n or der t o p ermi t TF S a nalys es t o be ca r r i ed

out , some 7 ,250 MW (net ) o f generat ion capaci ty w a s i n st al l ed i n t h e R epub l i c o f I r e la n d . O f

t h i s 6, 4 5 4 M W i s c o n ne c t e d t o th e n a t i o n al g r id a n d 79 6 M W i s c o n ne c t e d d i r e ct l y t o t he

d is t r ib ut i on sy stem. Sect i on s 4 . 1 to 4 .4 deta i l p lanned developments wi th respect to

g enerat i on ov er th e per i od c ov ered by th is TFS.

4.1 EXISTING AND PLANNED GRID-CONNECTED GENERATION

T h e 6 ,4 5 4 M W f ig u re f o r g r i d - c o nn e c t e d g e n er a t i o n c a p ac i t y i nc l udes g e n er at o rs th at

connected to the g r id in 2009, namel y the L i sheen Wind Farm in Co. T i pp er ar y (55 MW ), a n

increase in MEC at Coomacheo Wind Farm in Co. Cork ( 18 MW) and an increase in MEC at

Coomagear lahy Wind Farm in Co. Kerr y (3 8.5 MW).

A n u m b e r o f g e n e r at o rs h av e a p pl i ed f o r c o n n ec t ion t o th e g r i d . A t t he t i m e o f t he d a t a

f r e e z e, 1 9 con t r ac t s h ad b e e n s i g ne d , a gr e ei ng t o c o n n ect a t o ta l g en e r a t i o n c apa c i t y o f

2 , 1 1 7 M W t o t h e gr i d . The s e pl a n n e d g e n e ra t or s a r e l i s t e d i n T a b l e 4 - 1 w i t h t h ei r ex pec t e d

c onnec t i on dat es as at t he t i me of th e data f r eeze.

The fo l l owing connect ion ag reements s igned s i nc e the data f reeze date; Cui l leen 98.4 MW

OCGT p lant a t At h lone, Co. West meath, Sui r 9 8 M W O CG T p l a nt at C ah ir , C o . T i pp e r ar y ,

Caul st ow n 58 M W O CG T P eaki ng P l ant a t Caul stown, Co. Louth and Knoc knagreenan 70 MW

pumped storage pl ant Co. Cork .

Tabl e 4-1 P l anned Gr id-Connect ed Generat ion as a t Ju ly 01 s t 20 0 9

G enerat or D e s cr ip t i o n E x p e ct e d

Connect ion

D a t e

Bool t i ag h Wind Farm (Extensi on)

12 M W wi n d far m extension in Co. Cl ar e Aug-09

G ar v agh 5 8 . 2 M W wi nd f ar m i n C o . L e i t r i m A u g - 0 9

Bindoo Wind Farm (Extensi on)

22 MW wind farm extension in Co. Cav an Sep-09

B ogg erag h 57 MW wind farm in Co. Cork Sep-09


4-2

Tabl e 4-1 P l anned Gr id-Connect ed Generat ion as a t Ju ly 01 s t 2009 (Cont inued)

G enerat or D e s cr ip t i o n E x p e ct e d

Connect ion

D a t e

Aghada 431 MW CCGT in Co. Cork Nov -09

W hi t eg at e 4 4 5 M W CCGT in Co. Cork Nov -09

D r o m a da 4 6 M W wi n d f a r m i n C o . L i m e r i c k D e c - 0 9

Edenderry 116 MW Peaking P lant in Co. Of fa ly Dec-09

Knockacummer 87 MW wind farm in Co. Cork Jan-10

M u l r e av y 8 2 M W wi n d f a r m i n C o . D o n e ga l J a n - 1 0

Glanlee Wind Farm (Extensi on)

6 MW wind farm ex tension in Co. Cork Mar -10

Keelderry 29.8 MW wind farm in Co. Galway May-10

A t h ea 5 1 M W wi n d f a r m i n C o . L i m e r i c k J u n - 1 0

A t h ea W i n d F a r m ( E x t e ns i o n )

22 MW wind farm extension in Co. L imer ick Jun-10

C a s t l e d o c kr i l l 4 1 . 4 M W wi nd f ar m i n C o . W ex f or d D e c - 1 0

N o r e P ow e r 9 8 MW O CG T i n C o . Ki l k en n y M a y - 1 1

B al la k el l y 4 4 5 M W CCGT i n Co. L o uth A p r -1 2

C l o gh b o ol a 4 6 M W wi n d f a r m i n C o . K e r r y F e b - 1 4

Moneypoi nt W i n d F ar m

21 .9 MW wind farm l ocated at Moneyp oint coal - f i red power st at ion in Co. Cl are

N/A 8

4.2 PLANNED RETIREMENT/DIVESTITURE OF GENERATION PLANT

The d ivest i ture or c losur e o f generat ion pl ant c ou l d h av e a s i g ni f i c a nt i mp a c t o n t h e a b i l i t y

o f th e gr id to c ompl y w i th s tandar ds. U nder the Gr id Code, a min imum of 24 months not ice

i s r e q ui re d by th e T SO t o a d d r e ss t h e p o t e n t i a l i mp l i c at i o n s o f a n y g e n er a t i o n c l os u r es.

I t was announced in November 2006 that an agreement had been reached between ESB and

the CER to reduce ESB’s share o f the e lect r ic i ty market . Under the terms of the agreement

ESB must c lose or d ivest 1 ,300 MW of p l ant by 2010. One of the provis ions o f the agreement

i s t h at E S B m u s t s el l p e a k i ng c apa c i t y p la n t t o t al l i ng 20 8 M W , i n c l u d i ng s i t es a n d

in f rast ructure , at Rh ode and Tawnaghmore.

8 T h e r e i s c u r r e n t l y n o s e t d a t e f o r t h e c o n n e c t i o n o f M o n e y p o i n t w i n d f a r m .


4-3

The Aghada peaking uni t has subsequent ly be e n t r a n s f er re d t o T a w n a ghmo r e . C o n n e c t ion

agreements have been s igned wi th the DSO to th e ef f ect th at t w o 52 MW peaki ng uni ts w i l l

become DSO cost umers, connected at Tawnaghmor e.

I n F e b r u ar y 2 0 0 9 , E SB P o w e r G e n er at i o n c o n f i r med that i t intends to c l ose Poolbeg Uni ts 1 ,

2 a n d 3 a n d t h e st e a m t ur b i n e at M ar i n a b y e a r l y 2 0 1 0 . T h e l ar g er ga s t urb i n e a t M a r in a w i l l

r e m a i n o p era t i o na l .

In Ju ly 200 8, i t was an noun ced that th e Spani sh p ow e r c om p a n y , E n des a , h av e ag r e ed t o

p u r ch a s e G re a t I s l a n d a n d T a r b e r t gen e r a t i o n s tat ions as wel l as Rhode and Tawnaghmore

p e a k i ng pl ant s f r o m E SB . T h e e x ac t d e t ai l s o f th e f ut u r e o pe r a t i o n o f the s e pl a n t s ha v e y et

to be f ina l i sed by Endesa.

4.3 EMBEDDED GENERATION

On th e 01 s t o f Ju ly 2009, there was approx imatel y 79 6 MW of embedded generat ion p lant

i .e . , p lant connected to the di st r ibut ion system o r t o t he s y s te m o f a d i rect l y -connecte d

demand cust omer . Th is f igure compr ises combined heat and power (CHP) schemes, smal l

indust r ia l thermal uni ts and renewable genera t ion f rom wind, smal l hydro, land- f i l l gas

(LFG) and b iomass sources. Table 4-2 l is ts the ex ist ing embedded generat ion capa ci ty to tals

b y g e n e r at ion t y p e . T a b l e D - 3 i n A p pen d i x D p r ovi d e s d et a i l s o f t he e x i s t in g e m b e d d ed w i n d

farms and the i r capaci t ies .

Tabl e 4-2 Ex is t ing Embedded Generat ion as a t Ju ly 01 s t 2 0 09 , M W

Wind S m a l l

H y d r o

B i o m as s /

LFG

CHP Industr ia l P e a ki ng TOTAL

N e t C ap a ci t y ( M W )

512 22 33 116 9 104 796

E m b e d d e d gen e r a t or s red u c e t h e d e m a n d s u pp l i e d t hr o ug h th e t r a ns m i s si o n i nt e r fa c e

s tat ions. Forecasts o f demand at the re levant t ransmission inter face s tat ions, presented in

Table 3 -1 of Chapter 3 , take account o f the contr ibut ion of the ex is t ing non-wind embedded

g e n e rat or s 9. The Generat i on Adequacy Report 2009-2015 ( G AR ) f o r e ca s ts t h e t o ta l CH P a n d

non-wind renewabl e capaci ty to gr ow by about 5 MW per year .

4.4 WIND GENERATION

O ver the past f i f teen y ear s wi n d p ower generat ion in the Republ ic o f I r e l and has incr eased

f r o m 6 M W (on e wi n d f a rm ) t o 1 , 0 9 5 M W ( 7 9 wind farms) a t the beginning of Ju l y 2009.

9 B e c a u s e o f t h e v a r i a b i l i t y o f w i n d , a f i x e d c o n t r i b u t i o n f r o m e m b e d d e d w i n d f a r m s i s n o t t a k e n i n t o a c c o u n t i n t h e c a l c u l a t i o n o f t h e p e a k t r a n s m i s s i o n f l o w f o r e c a s t s . R a t h e r a n u m b e r o f w i n d s c e n a r i o s a r e c o n s i d e r e d i n t h e T F S a n a l y s e s .


4-4

F ig ur e 4 -1 sh ow s exi st i ng and p lanned t ransmiss ion-connected , d is t r ibut ion-connected and

the total con n ec ted win d power capaci ty at year end f rom 1992 to 2014. The graph

i l l u st ra t e s th e i n cr e a s e i n wi n d p o wer i n r e c e nt y e a r s .

0

500

1000

1500

2000

2500

3000

1992 1994 1996 1998 2000 2002 2004 2006 2008 2010 2012 2014

Year

MW

Transmission Distribution Total

F ig u r e 4 - 1 G ro w th i n W i nd C a p ac i t y , 19 9 2 t o 2 0 14

As at the 01 s t o f J u l y 2 0 09 , 9 1 wi n d fa r m s t ot al l ing 1 ,418 MW have s igned connect ion o f fers

a n d a re c o mmi tt e d t o c on n e c t i ng t o t h e t r a n s mi ss i o n or d i st r i b u t i o n n et wo r k s ov er t he n e xt

f ew year s . Tabl e 4 -3 show s th e t ota l amount of ex i s t i ng and c ommi t t ed w i nd g ener a t i on

capaci ty expected to be connected at the end of each year f rom the ex ist ing s i tuat ion at the

e n d o f 2 0 1 0 t o 2 0 1 6 . T he i n di v i d u al wi n d fa r m d e ta i l s a r e i nc lu d e d i n A ppen d i x D .

T a b l e 4 -3 Ex is t i ng a n d C om m i t te d W i nd C a p ac i t y Tot al s , MW

Connect ion 2009 2010 2011 2012 2013 2014 2015 2016

Transmiss ion 792 1 ,030 1 ,030 1 ,030 1 ,112 1 ,158 1 ,158 1 ,158

D i st r i but i on 753 9 73 1 , 067 1 , 092 1 ,092 1 ,288 1 ,288 1 ,355

Tota l 1 ,545 2 ,003 2 ,096 2,12 1 2 ,203 2 ,446 2,446 2,5 13

A t t h e t i m e o f t h e da t a f r e e ze , a t o t al o f 558 appl icat ions for wi nd farm connect ions

t o t al l i ng 1 4 ,10 0 MW h a d b e e n r ec e iv ed b y t h e T SO a n d D S O .

A t o t al of 1 ,3 1 6 MW o f wi n d g e n er at io n h a s been processed under the CER’ s Gate 2 d i rect ion

o n w i n d f a rm c o n n e c t i on s . T h e c o nne c t io n s t udi e s w e r e c arr i e d o u t w i th G a te 2 wi nd f a r ms

g r o up e d g e og r ap h i ca l l y , a s s e t o ut i n t h e C E R di rect ion. F ig ure 4-2 and T ab l e 4 - 4 i l l u st r at e

h o w G a te 2 w i n d g e n era t i o n i s d ist r i b u t e d ac ros s t he c o unt r y . A t t h e t i m e o f the d a t a

f r e e z e, 1 , 2 3 5 M W o f th e G at e 2 r e n ew a b l e g e n e ra t i o n c o n n ect i o n o f fer s ha v e b e e n a c cep t e d .


4-5

Table 4-4 Gate 2 Wind Generat ion Area Tota ls

B

A

C

G

E

F

D H1

H2

I

B

A

C

G

E

F

D H1

H2

I

F ig u r e 4 - 2 G a t e 2 Wi n d G e n e r a t i o n A re a s

A t t h e t i m e o f t h e d at a f r e e z e , a t ot al o f 1 0 , 1 7 9 M W o f g e n e r a t o r c o n n e c t i on a p p l i c at i on s a r e

b e i n g as s e ss e d a s p er t h e C o m mi ss i o n f or E n e rg y Reg ul at i o n’ s G a te 3 d i r e ct ion o n t he

g r o up p r o c es s i ng s c h em e f o r g e ner a t or s . I t i s cur rent ly expected that approx imatel y

4 ,000 MW of wind generat ion and approx imat ely 2 , 0 0 0 M W o f c o n v e nt i ona l g e n er at i o n w i l l

r e c ei ve c o nne c t io n o f f er s as p ar t of th is pro c es s . F i g ur e 4-3 a n d T a b l e 4 - 5 i l l u st r a t e h ow

G at e 3 g e n era t i o n is d i st r i b ut e d a c ros s t h e c o u ntr y .

“G a t e 2” Ar ea Tota l G enerat ion (MW)

A (Nor th West ) 201

B (M i d N or th W e st ) 1 0 4

C (Mid lands) 13

D (M i d Wes t ) 6 6

E ( S o ut h W es t ) 5 9 2

F (South West ) 44

G ( No r t h E a st ) 14

H1 (M idlands-South West ) 162

H 2 ( S o ut h E as t ) 1 1 8

I (South) 2


4-6

Tabl e 4-5 G ate 3 Generat ion Area Tota l s

B

A

G

E

F

D H1

H2

B

E

H1 H2

IK

F

G

D

J

C

A

F ig ure 4-3 Gate 3 Wi nd Generat i on Areas

G at e 3 A r ea Tota l G enerat ion (MW)

A (North West ) 261

B (M id Nor th West ) 1 ,828

C (Midlands) 33 8

D (M i d W e s t ) 1 2 1

E (South West ) 1 ,662

F ( S o ut h W es t ) 9 7

G (Nor th East ) 821

H1 (M idlands-South West ) 506

H2 (South East ) 2 ,184

I (South) 123

J (M i d E a st ) 2 , 1 7 5

K (South) 62

05transmission system Performance5.1 forecast Power flows

5.2 compliance with Planning standards

5.3 short circuit currents


5-1

5 TRANSMISSION SYSTEM PERFORMANCE

T h i s c ha p t er d e s cr i b es t h e f u t ur e per f or m a n c e o f th e t r a n smi s si o n n e tw o r k i n t erms o f

f o r e ca s t p ower f l ow s , c om p l i a n c e wi t h pl a nni ng st andards, and sh or t c i rcui t levels .

Th e anal ys is o f t h e sh ort c i rc u i t c urrent s i s up dated in th is TFS and inc l udes any changes to

t h e ex i st i ng and p lanned t r ansmi ss i on net w or k dat a and th e ex is t i ng and pr oj ect ed demand

and generat ion data s i nce the Ju ly 2009 data f reeze.

5.1 FORECAST POWER FLOWS

The power f l ow at any g iven t ime depends on demand levels and the output f rom each

ge ne ra tor . Th er e ar e man y poss i bl e combinat ions o f generator output s ( i .e . , d i spat ch es)

that can meet the syst em demand requi rements at any g iven t ime and many poss ible

demand scenar ios . P lanned addi t ions o f genera t i o n, a s d e t a i l e d i n T ab l e s D - 2 a nd D - 3 i n

A p p e n d ix D, c r e at e a g re a t e r l ev el o f g e n er at i on d i s p at ch v a r i a bi l i t y wi th wh ic h the g r i d

must cope.

In examining network per for mance and gr id capabi l i ty for new generat ion and demand, a

r a n g e o f g en e r a t i o n di sp a t ch e s i s c o n s i d er e d . A s st a te d i n S e ct i o n 1 . 2 i n C ha pt e r 1 ,

d i s p at ch e s w e r e p r ep a r e d o n a n a l l - i s l a n d b asi s , w i th pow er f low s ac r oss th e ex i st i ng

275 kV and p lanned 400 kV cr oss-border c i rcui ts p e r mi t t e d . D i sp a tc h es con s i d er e d f or 2 0 13

and 2016 inc l uded imports and expor ts of power across the pl anned East -West

in terconnector between I r e land and Great Br i ta i n .

5.2 COMPLIANCE WITH PLANNING STANDARDS

F igure 5 -1 and F igure 5 -2 indicate the areas of the networ k l ike ly to be outs ide ther mal , i .e .

c i r c u i t l oa d i n g , a n d v ol t a g e s tandards in 2010, 2013 and 2016 based on the assumpt ions on

t rans mi s sion r e i n for cemen ts , d eman d and genera t i o n o ut l i n e d i n th i s st a te m e nt . T h es e

areas ar e h ighl ighted by orange sh ading on the maps.

Th e f ig ures i l l ust rat e h ow t h e netw or k per for ms agai nst p l anning s tandards. I t sh ould be

n o t e d h o w ever t ha t s o m e i n c i d e nt s , suc h a s a f a ul t o n a t r a n sf o r m e r or u n d e r gr o u n d ca b l e ,

m a y t a k e a l o n g t i m e t o r e p a i r a n d c o u l d tem p or a r i l y c h a nge t h e p er f orm a n c e o u t l ook . A

lengthy outage of a t ransformer or cable could weaken the network which could impact on

system f l ex ib i l i ty and on generat ion const ra int s .


5-2

The 2010 snapshot shown in F igure 5 -1 indi cates that a number o f a reas ar e outs ide

s t a n d ar d s p e n d i ng c om p l et i o n o f o n g o i ng pro jec ts . F igure 5 -2 shows that networ k

p e r f or m a n c e i s e x p ec t e d t o i m p r ov e i n 2 0 1 3 w h en t h e s e r e i nf o r c e me n t s a r e c o m pl et e d , i n

p a r t i c ul ar f o l l o w i n g c o mp l et i o n o f t h e pl anned 220 kV Moneypoint -Ki lpa ddoge c i rcu i t . The

a n a l y si s f or 2 0 1 6 s h o w s a g r o wi ng n u m b e r o f a r eas outs ide st andards, i l lust rat ing the ever -

changing demands on the gr id and the need for cont inuous devel opment . The Transmiss ion

S y s t e m O p era t o r ( T S O ) h a s pl a n s i n p l ac e t o a ddr ess many of th ese pr oblems and i s ac t iv el y

c o n s i d er i n g o p t i o ns f o r a d d r e ss i ng o t h er f u t ur e n e t w o r k p r obl e m s . I t sho u l d b e n o t ed w h e n

assessing the 2016 per formance, that approx ima t el y 5 0 % o f G a t e 3 w i n d g e n er at i o n w as

assumed to be connect ed by then.

Areas of the network not shaded in the d iag rams are expect ed to be wi th in s tandards based

on cu r re nt assumpt i on s. Howev er , the c i rca 6 ,000 MW of generat ion cur rent ly ex pected to

r e c ei ve o f f er s i n G at e 3 m a y s i g ni f i ca n t l y i m pa c t o n n et wo r k p er f o r ma n c e , p ot e nt i a l l y

put t ing some of these ar eas outs ide s tandards. S i m i l ar l y , o th e r d e v el opme n t s s uc h a s th e

connect ion of a new l arg e g enerator or demand may put areas o f the networ k outs ide

s t a n d ar d s . In s u c h c a s es , f ur t h e r i n v e s t m e nt wi l l be requi red to restore the network to

s ta ndards.

F ig u r e 5 - 1 Net w or k P er f or m a n c e i n 201 0

2010


5-3

F ig ure 5 -2 Networ k P er for mance in 2013 and 2016

5.3 SHORT CIRCUIT CURRENTS

A l l ne twork equi p ment must be capable of car rying the cur rents that may occur in the event

o f a s h o r t c i r c ui t f a ul t . I n p a r t i c ul ar , c i r c u i t b r e ak e r s m u s t be c a p a bl e o f o p e n i n g t o i s ol a t e

a f a ul t , the r e b y mi n im i s i ng r is k t o per s o nn e l , p r ev e nt i ng d a m age t o t ra n smi s si o n

equipment , and maintain ing syst em stabi l i t y , sec u r i t y a n d qua l i t y o f s u ppl y .

The t ransmiss ion system is des igned and opera t e d t o m aint a i n sh or t c i rc u i t l ev el s b e l ow

the s tandard equipment ra t ings l is ted at each v o l t ag e l ev el i n T a bl e 5 -1 . I n p l a n nin g t h e

system a 10% margin is appl ied, so that 220 kV shor t c i rcu i t cur rent s , for exampl e, wi l l be

kept be low 36 kA.

I t should be noted that Gr id Code Versi on 3 .1 ( re l eased in May 2008) conta ins a

modi f i c at i on w hi ch st ipul at es t h at f au l t l ev e ls a t desig nat ed s t at i ons may be a l l ow ed t o

increase to 31 .5 kA. I f necessary , the equipment a t these s tat ions is to be modi f i ed or

r e pl a c e d i n o r d e r t o com p l y wi th th i s n e w r a t in g . T h e s t at i o n s c ur r e nt l y d e sig n a t ed f o r

operat ion o f the 110 kV equipment up to 31 .5 k A , a s p r o p o s ed b y t h e T S O , a r e; B ar na h el y ,

C o l l e g e P ar k, C o r d u f f , F in g l a s , K i l b ar r y , K n ockrah a, Louth, Mar ina, Raf feen and Trabeg. The

TS O wi l l a nnual ly p ubl i sh an up dated l is t of des ignated st at ions.

2013 2016


5-4

L o c al s h or t c i rc u i t c ur r en t i s a f ac t or t o b e c o n si d e r ed i n the c o n n e c t i on o f n e w g en e r a t i o n

or demand. The Gr id Code requi res that users connect ing to the t ransmiss ion syst em design

thei r p l ant and apparatus to wi thst and the shor t c i rcui t cur rent s set out in Table 5 -1 .

C h a n g es i n t h e n et w or k o r th e a dd i t i o n of gen er a t i o n ca n b r i ng a b o ut an i n c r ea s e in t h e

shor t c i rcu i t cur rent s at a s tat ion nearby. Wh ere the forecast cur rents would ex ceed th e

r a t i n g of a c i rc u i t b r ea k e r o r ot her e q u ip m ent , i t w o uld b e e s s e n t i a l t o r e pla c e th e

e q u i p m e nt w i th h igh e r r a t e d p l a n t o r ta k e ot h er m e a s ures t o red u ce t h e s h or t c i rc u i t

c u r re n t s .

Table 5 -1 Standard Equipment Rat i ng and Maxi mum Design Sh ort Ci rc u i t Currents

Vol tage Level St andard Equi pment Sh or t C i rc ui t Rat i ng

400 kV 50 kA

220 kV 40 kA

1 1 0 k V I n D u bl i n 2 6 k A

O u t si d e D u bl i n 2 5 k A

Desi gn at ed s i tes 31 .5 kA

S h o rt c i r c ui t c u r r e nt s wer e c al c ul ate d f o r a l l gr i d b u s e s i n a c c or d a n c e w i th i nt e r n at i o n al

s t a n d ar d s . Th e a n al y si s w a s c ar r i e d o u t f o r s i ng l e - p h a se a n d t hr e e - ph a s e f a u l t s f or wi n t er

peak and summer val ley, for the years 2010, 2013 and 2016. A descr ipt ion o f the calculat ion

method and the resul ts ar e g iven in Appendix E as wel l as an ex pl anat ion of the terms used.

A n a l y si s w as c ar r i e d o ut f or th e w in t e r pea k as t h e r e s ul t s s h o ul d i nd i c at e t h e m a x i m u m

short c i rcu i t cur rent s on the system. Conversely , a n a l y si s o f t h e s u m me r v al l e y w a s ca r r i e d

o u t as t he r es u l t s s h o ul d i n di c at e th e m i ni m u m sho r t c i rc u i t cur r e nt s .

The generat ion d ispatches for the wi nter peak and summer val ley s tudies are presented in

T a b l e D - 4 i n A p p e n d i x D. F o r t h e c al c u l at ion s o f s h o rt c i r c ui t c u r re n t s at w i n t er p e a ks , a l l

o ther g e n er ator s ar e mod el led as d ispatched at zero MW. Th is measur e ensures a h igh

i n f e e d t o f au l ts f r o m al l l o c al g e n er a t or s our ces in the s tudies ensur ing that the most

c r i t i c a l p ot en t i a l sc e n a r io i s c o n s ider e d f or th e ca l c ul at ion o f s h or t c i r c ui t c ur r e nt s at e a ch

b u s . F or t h e c al c ul at i o ns o f s ho rt c i r c ui t c u rr e n ts a t s u m m er v al l e y s , g en e r a t or s th at w er e

n o t di s p at ched w er e n o t s y n c hr o n i sed t o th e s y ste m .

The resul ts in Appendix E inc l ude RM S break cur rents , peak make currents and X/R rat ios .

I n s u m m a r y, th e RM S br e a k i s a n ind i c at i o n o f th e sh or t c i rc u i t c u rr ent s t h at a c i r cu i t

breaker may have to inter rupt i .e . , open. The peak make fau l t cur rent is the maximum

c u r re n t th at a c i r c ui t b rea k e r m a y h av e t o m a ke i .e . , c l o s e o nt o , a t th e i ns t a n t of th e f a u l t .

T h e X / R r at io i s d e p e n de n t o n t h e pr o xi m it y o f th e st at i o n to g e n er at i on. A ver y h ig h X / R

r a t i o , a s f o r D u bl i n s t at ion s , ar i se s f r o m th e f a ct t ha t th e st at i o n i s h ea vi l y i n t er c o n nec t e d


5-5

t o t he s u rr oun d i n g n e two r k a n d i s c lo s e t o c o n c ent r at i o n s of g e n e ra t i o n . T h i s l e a ds to h ig h

shor t c i rcui t cur rent s , par t icul ar ly peak make cur rents .

The s tudies assume that the networ k is in the normal in tact condi t ion (as indicated in th e

p o w e r f l o w d i ag r a ms ) and t h at a l l c i r cu i t s c o n ne c t e d t o a bus c o n tr i b ute t o th e fa u l t . T h e se

r e s ul t s c or r es p o n d t o t ota l b u s ba r s ho r t c i r c ui t cur r e nt . T h e s h o rt c i r c ui t c u rr e n t t ha t c o u l d

f l ow t hr o ug h e a c h i n di v id u a l c i r cu i t b r e a k er m a y b e l e s s t h an t h e t o ta l bus b a r s h or t c i rc u i t

c u r re n t . F i gur e 5 - 3 pr e se n t s th e sh or t c i rc u i t c urr e n t r es u l t s f o r th e wi n te r p e a k 2 0 13 c a se

as a percentage of s t andard equi pment rat ing . Tw o percentage rang es ar e repr esented by

d i f f er e n t c ol o u rs a s i nd i c at e d . The o r a ng e dot s rep r es ent s t at i o n s w h er e sh o rt c i r c ui t

cu r re nts may exc eed 80% of th e s tand ard rat ings and th e purple dots between 50 and 80%.

The re s ul ts in d i c ate that i n most o f the countr y s h o rt c i r c ui t c u r re n t s ar e r e l a t iv e l y l o w ,

w h er e a s sh or t c i r c ui t c u rr e n t s at a n u m b e r o f s t at i o n s i n Dub l i n a n d C o r k a r e a b o v e 80 % o f

t h e s ta n d a rd r at i ng s b ec a u s e of t h e h i gh c o n c ent r at i o n o f ex i st i ng a n d p l a n n e d g e ner a t i on

i n t h os e a r ea s . S h o r t c i r c u i t c u r r e n t s a r e a l so h i gh at Louth , w h er e th e mai n i nter c onnec tor

t o N o r th e r n I r e l a n d i s c on n e c t e d , a nd a t T a r ber t , where a new submar ine cable connect ing

t h e Ta r b er t a r e a t o Mon e y p o i n t g e ner a t i o n st at ion i s ex p ec te d t o b e c om p l et e d i n 2 0 1 3 . The

T S O wi l l c on t i n u e t o mon i t or sh o rt c i r c ui t c u rrents at these s tat ions to ensure that they

remain wi th in safet y s tandards.

>80% of the s tandard rat ing s

5 0 – 80% o f t h e st a n d ar d r at i ng s

F igure 5 -3 Gr id Busbar Short C i rc ui t Cur r ent s f or W i nter Peak 2013

06oVerView of transmission system caPability analyses6.1 transfer capability analyses for new demand

6.2 factors impacting on results


6-1

6 OVERVIEW OF TRANSMISSION SYSTEM CAPABILITY ANALYSES

T h i s c ha p te r d e s c r i b e s th e a n al y s es c a rr i e d o u t t o d e ter mi n e t h e c a pa b i l i t y o f t he gr i d t o

accommodate addi t ional demand at var ious par t s o f th e net w or k . T h e r e s u l t s o f t h ese

a n a l y s es , t og e th er wi th i n f o r ma t i o n i n o th er ch ap t e rs , pr ov ide th e b a si s f o r th e st a te m e n t s

o f opportuni ty in Ch apter 8 .

The analys es were car r ied out for three speci f i c years :

• 2010: Thi s i s th e f i rs t year o f the sev en-year per i od of t h e Transmi s si on Forec a st

Statement (TFS) . The in format ion pr ovided for 2010 g i v e s d ev el o p er s a u s ef u l i n di c at i on

a s t o t h e o pp o r t u ni t i e s th a t ex i st i n th e s h or t - t e rm.

• 2013 : Th is is the mi d-year o f the seven-year per iod. Beca use of typ ical lead-t imes for

c o n s tr u c t i o n o f d e ma n d p l a nt , t h i s yea r r e pr e s e nt s t h e m o r e r e al i st i c b egi n n i ng o f the

p e r io d o f i nt e r e st f o r dev el o p er s at a p re - f e a si b i l i t y s t a g e w i sh i ng t o con n e c t t o t h e

t ransmi ssion system.

• 2016: Th is cov ers t h e f i nal year of t he TFS, which extends to winter 2016/17.

S t u d i es w e re c a r r i e d out f o r th e s u m m e r a nd f o l l o wi n g w i n t er o f e a c h y e a r u s i n g

i n f o r ma t i o n d e s cr i bi n g t he ex is t i n g a n d pl anned t ransmiss ion system as know n at the

beg i nning of Ju l y 2009. The base case g enerat i on d i spatc h sc enar i os used f or t h e st udi es

a r e p r es e n t ed i n T a bl e D -4 i n A pp e n d i x D .

The l oca t ions an aly sed for n ew d emand have been carefu l ly rev iewed based on feedback

f rom indust ry sources. Th e ch osen st at ions have been ta i lored to match more c l ose ly the

needs of cust omers.

I t s h o ul d b e n o t e d t h a t t h e r e s ul t s o f t h e s e st udies are dependent on the assumpt ions made

about generat ion and demand, and on the complet ion dates o f network development

pro jects as descr ibed in prev ious chapters . Factors that may in f luenc e the resul ts ar e

d i s c us s e d i n S e ct i o n 6 . 2 .

6.1 TRANSFER CAPABILITY ANALYSES FOR NEW DEMAND

The g r id is p l anned to meet forecast demand s at a l l s ta t ions in the country . The demand

forecast for each 110 kV s tat ion is a propor t ion of t h e o v er al l s y s t e m d e ma n d f or e c as t b a s ed

on h ist or ical demand dis t r ibut ions. Future de mand customers that have s igned connect ion

agreements are a lso inc luded in st at ion demand forecasts .

W hi l e a d d i t io n a l d e m a n ds a b o v e t h e f o r e ca s t l eve l s ar e n o t ex pl i c i t l y c a ter e d f or i n net w or k

p lans, there may be capac i ty for such addi t ional demand inherent in the network at cer ta in

l o c at i o n s . New d e m a n ds c a n g e n er al l y l o ca t e i n an area that has excess generat ion capaci ty


6-2

as th is wi l l reduce power f lows out o f the ar ea. A l ternat ivel y, the addi t ion o f t ransmiss ion

in f rast ruct ure genera l ly prov ides a s tep increase in network c a p ac i t y w h i ch m a y p e r m it

demands h igher than forecast levels , as i l lust rated in F igure 6-1 . The b lue l ine represents

t h e r eq u i r e d c a p a ci t y a t a p a r t i c u l ar p o i n t i n the networ k. The red l ine represents the

instal led network capaci ty . Changes in insta l led capaci ty genera l ly come in d isc rete steps,

t h us pr ov i ding sp a re ca pa c i t y f or a per i od of t i me.

F i g u r e 6 - 1 I l l u s t r at i o n of T y p i c al S t ep C h a ng e i n Net w or k C ap ac i t y

F ig ure 6-2 i l l ust rates the demand prof i l e for a repr esentat ive st at ion. The bl ue l ine

represents the demand forecast a t the s tat ion. The green bars represent a new step

i n c r ea s e i n d e m a n d . T h e a n a l y si s c ar r i e d o u t f or th is TFS examines the gr id ’s capabi l i ty to

ac c ept such i ncr eased demand abov e f or ec ast l ev el s a t s e l ec t e d 1 10 k V s t a t i o ns . T h e

s e l ec t e d 1 10 k V s t a t i o ns , whi ch f ee d p r i nc i pal towns and demand centres d is t r ibuted

t hr o u gh o ut th e c o u n tr y , a r e sh o w n in F i g ur e 8 -1 in Chapter 8 . The resul ts o f th is analysis

a re u s e fu l i n i d en t i fy i ng op p or tuni t ies for the connect ion of new or increased demand of a

s ize typ ica l o f indust r ia l deve lopment i n t h e Rep ubl ic of I r e l a nd.

I n s t a l l e d C a p a c i t y

Y e a r s

R e q u i r e d C a p a c i t y

S p a r e C a p a c i t y

M W


6-3

F igure 6-2 Demand Prof i le a t Typi cal Stat ion

The method of analys is is deta i led in Appendix G. In summary, wh en demand in an area

increases, i t must be suppl ied by an increased output f rom generat ion uni ts . An incrementa l

power t ransf er is c reated. The method for th i s s t u d y, th e r ef o r e, i nv o lv e s m o del l i ng

i n c r e me n t al p o w e r t r a n s fe r s b et w e e n c e n t r e s o f ex is t ing generat ion and potent ia l demand

a r e a s . Th e t r a n sf e r l i mi t i s rea ch ed w h e n t he f i rs t c i r c ui t o v er l o a d o r v ol t ag e p r o b l e m

o c c u rs f o l l ow i ng a c i rcu i t or g e n erat o r o ut ag e . O u t ag e s dur i ng th e mai n t e n a nc e o f k e y

c i rc u i t s w ere c o n si d e red i n t h e s e s tu d i e s . D ynamic s tabi l i ty problems were not assessed. I t

s h o ul d b e not e d th at o nl y p ro b l e ms t h at ar e s i gni f ic a n t l y exa c e r b at e d by t h e t r a ns fer a r e

r e l e v a nt t o th e a n a l ys is .

I n a s s e s si ng o p p or t u ni t i e s f o r n ew d e m a n d s , t h e T F S con s i d er s t h e c a p a bi l i t y o f t h e

t ransmi ss ion g r id onl y . The capabi l i ty o f the d is t r ibut ion system is not addressed. The

impl icat ions for generat i on adequacy o f demand growth abov e the median forecast leve ls

ar e deal t wi th separ a t el y i n th e TSO’ s Generat ion Adequacy Report 2010-2016.

6.2 FACTORS IMPACTING ON RESULTS

The resul ts o f the analyses desc r ibed in th is chapter , and in the appendices, a re based on a

set o f assumpt ions about future demand growth , generat ion connect ions and t ransmissi on

developments . The key forecast fact ors on which the resul ts depend are dynami c and,

t h er e f or e , t h e r ea l i t y t h a t e m e r g es w i l l n ot exac t l y matc h th e f or ec ast s . Consequent l y , th e

r e s ul t s , w hi le r ea s o n a bl y i n di c at iv e, s h o ul d n ot be i nt e rpr et ed a s d e f i n i t iv e p r oj e ct i ons .

The factors l ikely to have an impact on the outcomes inc lude:

25

3 5

4 0

4 5

2007 2008 2009 2010 2011 2012 2013

M W

3 0

50


6-4

• the s ig ning of a connect ion ag reement by a ne w g e n e rat or - th e G at e 3 p ro c e s s i s l i k el y

t o r e s ul t i n c o n n e c t i o n o f f e r s b e i ng i ss ued for 6 ,000 MW of convent ional and wind

g enerat i on;

• d e l a y s i n con n e c t i o n o f c o m m i tt e d new g e n e ra t i on;

• c l o s ur e / div es t i t u r e o f ex i s t i n g g e n e ra t i o n st a t i o ns ;

• c h a ng e s i n t h e ec o n o m y w h i c h g ive r ise to consequent ia l ch anges in the overa l l demand

for e lect r ic i ty ;

• c h a ng e s i n d e m a n d i n a p a r t i cu l ar r eg i o n o r ar e a , a r i s i ng f r om n e w i n dus t r y

developments or c losur es ;

• d e l a y s i n t he p ro vi s i o n o f n et w o rk re i n f or c e m e nt s;

• select ion and const ruct ion of new reinforcement developments wh ich may s igni f icant ly

increase n etwor k cap aci ty .

07network caPability for new Generation7.1 Grid 25

7.2 Gate 3 and post gate 3 generation applications

7.3 Generation connection opportunities created by grid 25

7.4 impact of gate 3 and post gate 3 on capability for new generation


7-1

7 NETWORK CAPABILITY FOR NEW GENERATION

T h i s ch a pt e r p r ov i d es i n d i c at iv e i n f or m a t i o n o n th e o pp o rt u ni t i e s f o r g e ner a t or c o n n ec t ion s

b a s e d o n E i r G r i d’ s gr i d d e v el o p m ent s t r a t eg y, G RI D 25, a nd t h e G at e 3 gr o u p pr oc e s si ng

s c h e m e f or gen e r a t or s .

7.1 GRID25

Over the next 15 to 20 years , major ch anges wi l l take pl ace in I re land’ s e l e ct r i c i t y n ee d s , i n

i t s s o ur c es o f f u e l a n d i n i t s f l e e t o f p o w e r s t at ions . Ch a ng e w i l l i ncr easi ngl y be dr iven by

issues of energy secur i ty , compet i t iveness, c l imate ch ange and by the need to move away

f r o m i m p or te d f u el s .

T h e N a t i o n al E l e ct r i c i t y G r i d i s a v i t a l cha n n el f or s u pp l yi n g r e l i a bl y , s u s t ai n a ble a n d

renewabl e energy and for open comp et i t ion wi th i n t he s ec to r . A s t ron g t r a ns m i ss i on g r id

wi l l br ing the energy suppl ies which wi l l enable I r e l and to pr osper economical ly and to

p r o vi d e g o od q u al i t y o f l i f e t o i t s p e op l e .

R e i n f o r c i ng a n d u pg r a di n g t h e t r a n smi s si o n s y ste m i s r eq u ire d i n o r d er to m a i nt a i n a s t r o n g

gr id . The capaci ty o f the bulk t ransmissi on syst em, c o m p ri s in g c i r c ui t s at 220 kV or h igher ,

h a s r e m a i n ed l a r g el y u nc h a ng e d i n t h e l a st 2 0 years , a per iod that has seen a grow th of

150% in the e lect r ic i ty demand. E i rGr i d ca l c u l a t es t h at t o fa c i l i ta t e t h e nec e s s ar y i ncr e a s e

in renewable generat ion and to adeq uately meet the demands of the e lect r ic i ty cust omer ,

the capaci ty o f the bulk t ransmiss ion sy stem wi l l need to be doubled by 2025.

T h e st r at eg y f o r th e l o ng t e r m d e v el o p m e nt o f I r e land’s E l ec t r ic i ty Gr id for a sustai nable

and compet i t ive future is set out in GRID25. G R ID 2 5 w i l l p r ov i d e t ransmiss ion capaci ty for

increased electr ic i t y demand, ne w convent ional generators and large amounts o f renewable

g enerat i on.

F u r th er d et ai l s o n G R I D 25 a r e av ai l ab l e o n th e E i r G r i d web s i te (www.ei rg r i d .com).

7.2 GATE 3 AND POST GATE 3 GENERATION APPLICANTS

The TSO and DSO have rece ived a considerabl e num b e r o f n ew a p pl ic a t i ons f o r c o n n ec t ion

o f generat ion to the system. I t i s cur rent ly ex p ect e d t h a t c i r ca 4 , 0 0 0 M W o f w i n d g e n er a t i o n

and approx imatel y 2 ,000 MW of convent ional generat ion wi l l receive connect ion o f fers i n

G at e 3 . F ig ur e 4 -3 a n d Ta b l e 4 - 5 i l l us t r at e h ow G at e 3 g ener a t i on i s d i st r i but ed across th e

c o u n t r y . P ost G a t e 3 th er e ar e c ur r en t l y a f ur ther 2 9 0 a p pl ic a t i o n s f or ren e w a b l e ( ma i n l y

w i n d f ar m s ) c o n n e c t i o n s t o t al l i ng c i rc a 8 , 60 0 M W.


7-2

7.3 GENERATION CONNECTION OPPORTUNITIES CREATED BY GRID25

On January 29 t h 2 0 1 0 E i r G r i d p u bl ish e d t he G ate 3 F i r m A cc e s s Q u a nt i t i e s , i n a cc or d a n c e

w i t h t h e G a t e 3 g r o up pr o c e ss i ng s ch e m e . T h e publ ic a t i on det a i l s th e pot ent i a l leve l s of

f i r m n e t wo r k a c c es s av ai l a bl e i n th e e l e ct r i c i t y gr i d f o r e a ch G at e 3 pr o j ec t f or ea ch yea r u p

t o 2 0 23 , ta k in g ac c o u nt of th e pr o p o se d d ev el o p me n t s o ut l i n ed i n G r i d 2 5 .

For the purposes o f th is T ransmiss ion Forecast Statement , Table 7 -1 compi les the Gate 3

F i r m Ac c es s Q u a n t i t i e s t o i l l u st r a t e t h e l e v el of ca p a ci t y av ai l a bl e o n t h e e l e ct r i c i t y g r i d t o

accommodate addi t ional generat ion, for three stages o f the seven year per iod covered by

the TFS – 2010, 2013 and 2016. Table 7 -1 i l lust rates that by 2016 the developments

a s s oci at ed wi th Gr i d 2 5 c r ea te f i rm capac i ty on the gr id to accommodate more than

2 ,000 MW of Gate 3 generat ion.

T a b l e 7 - 1 i s b a s e d di r ec t l y o n t h e G at e 3 F i rm Access Quant i t ies and the associ ated

assumpt ions. Detai ls on the Gate 3 F i rm Access Q u a n t i t i e s a r e a v ai l a bl e o n t h e E i r G r i d

websi t e (w ww . e i r g r id . c om).

Tabl e 7 -1 Capabi l i t y f or New G ener a t i on for each r egi on, MW

Region 2010 2013 2016

East 427 745 1 ,047

North-east 33 80 202

North-west 0 123 159

South-east 52 100 188

South-west 0 0 227

West 0 9 2 3 0 6

Total 51 2 1139 21 29

7.4 IMPACT OF GATE 3 AND POST GATE 3 ON CAPABILITY FOR NEW GENERATION

The t ransmiss ion system upgrades and re infor c e m e nt s a s s o ci at e d w i t h G R ID 25 w i l l

i n h er e n t l y cr e a t e s ig n i f ic a n t c a pa ci ty o n t he g r id t o a c c o mmo d a t e n e w g e n e r at i o n . I f n e w

g e n e ra t or s s ig n ag r e e me n t s f or c on n e c t i o n i n a n a re a t ha t h a s r e ce iv e d i n cr e a sed gr id

capaci ty as a resul t of Gr id25 syst em re in forcements , they wi l l us e up some or perhaps a l l

o f th e av ai labl e c a pa c i t y i n t h at a r ea .

The quant i t ies prov ided in Table 7 -1 are based on a n a l y si s ca r r i e d o ut on t h e ap pl ica t i o ns i n

Gate 3 . I t i s reasonabl e to assume that addi t ional capac i ty , ov er and above t h a t i n di c at e d i n

Tabl e 7 -1 , wi l l be avai l abl e on var ious par ts o f th e g r i d t o ac c ommodat e s ome p os t G at e 3

g enerat i on. H ow ev er , g iv en th e sc ale of g enerator appl i c at ions i t i s unl i ke l y , ev en w i th t he

s igni f ican t n etwor k expa n si on assoc iat ed wi th G R I D 2 5 , t h at t h er e wi l l b e c a p a ci t y o n t h e

gr id to provide f i rm access to a l l post Gate 3 appl icat ions before 2025.


7-3

T h e m a n n e r i n w h i ch p os t G a t e 3 a pp l i c at i o n s wi l l b e pr o c es s e d h as y et t o b e d e cid e d b y

the Commiss ion for Energy Regul at ion (CER) .

Up- to-da te in format ion on appl icat ions, new generat ion co nnect ion ag reements and the

process for obta ining a formal connect ion o f fer are avai lable on ww w . ei r g r i d .c o m. Befor e

ma k ing a ny commer c i a l d ec i s i on s d ev elopers sh ould contac t E i rGr id for d i scuss ions on thei r

proposed developments .

T h i s T F S i s pub l i s h e d s o l e l y f or th e pur p o s e s of Sec t i o n 3 8 of t h e 19 9 9 E l ec t r i c i t y Ac t and i s

n o t i n t e n d e d t o h a v e a n y l e g al e f f e ct i n r e l at i o n t o t h e n eg o t i a t i o n o f c o nt r ac t u al t erms f o r

connect ions to the t ransmission system.

08network caPability for new demand8.1 incremental transfer capability results for new demand

8.2 opportunities for new demand

8.3 impact of changes since the data freeze

8.4 how to use the information for demand


8-1

8 NETWORK CAPABILITY FOR NEW DEMAND

The nat ional g r id is be ing p lanned to meet ant ic i p a t e d d e m an d g r o wt h at a l l s t a t i o n s o n t h e

gr id . Appendix C prov ides proj ect ions o f demand a t e ach s t a t i o n . Thi s ch a pt e r p r e sent s t h e

re s ul ts o f analy ses o f the capabi l i ty o f the gr id to accommodate incr eased demand, above

pro je cte d deman d lev els, an d d i scusses the opportuni t ies for increased demand of a s ize

typ ical of indust r ia l development in the Republ ic o f I re l and. Twenty-nine 110 kV st at ions,

which f e ed p r i nc i pa l town s an d d emand centres th roug hout th e country , were ch osen for

t h i s a n al y s is . T h es e ar e sh o w n i n F ig ur e 8 - 1 .

F igure 8-1 110 kV Stat ions Studied for Demand

8.1 INCREMENTAL TRANSFER CAPABILITY RESULTS FOR NEW DEMAND

The method of anal ys is used to determine the capabi l i ty o f the gr id to accommodate

addi t ional demand is descr ibed in Ch apter 6 and i n m o r e det a i l i n A p pen d i x G . T h e r e s u l t s

o f the anal yses are presented in Ta bl e 8-1 . Th ese indicate the amount o f addi t ional demand,

in excess o f proj ected demand, that coul d be accommodated at ea ch of the twenty-n ine

110 kV st at ions, wi thout the need for addi t ional g r i d r e i n f or ce m e n t . T h e resul ts ar e g iven to

t h e near est 10 MW .


8-2

Tabl e 8-1 Capabi l i t y f or Addi t i onal Demand at 110 kV St at ions, M W

Region Station 2010 2013 2016

North-east

Drybridge 120 70 60

Mullagharlin 50 50 4 0

Shankill 20 90 90

North-west

Carrick-on-Shannon <10 P 1 60 60

Castlebar <10 P 1 3 0 20

Letterkenny <10 P 1 20 3 0

Moy <10 P 1 20 20

Sligo <10 P 1 9 0 9 0

East

Carrickmines <10 P 2 1 10 100

College Park 70 70 70

Mullingar <10 P 1 4 0 6 0

Newbridge 3 0 1 0 0 8 0

Portlaoise 10 120 70

Thornsberry 20 3 0 70

West

Athlone <10 P 1 70 60

Cashla <10 P 3 180 120

Ennis 7 0 80 14 0

Galway <10 P 3 70 60

South-east

Arklow 10 80 70

Carlow 20 3 0 4 0

Kilkenny 10 3 0 13 0

Killoteran 70 60 60

Wexford 10 4 0 3 0

South-west

Cahir 20 20 10

Cow Cross 20 80 80

Kilbarry 20 80 50

Limerick 50 9 0 13 0

Trabeg 3 0 1 0 0 1 1 0

Tralee 3 0 9 0 80

The superscr ipts in Tabl e 8-1 prov ide a c ross re ferenc e between the low Incrementa l

T ransfer Capabi l i t ies ( ITCs) and the tables in Appendix F wh ich prov ide addi t ional

i n f o r ma t i o n r e ga r di n g the c o n st r ai n ts l i mi t i n g the ITCs and the l ikely sc al e of development

requir ed to increase the ITCs. Reference number s pr ef i x ed w i th a “P” i ndic a t e th at th e

T r a n s m i s s i on S y s t e m O pe r a t or ( T SO ) h a s i n i t i ated speci f i c pro jects which wi l l ov ercome the

c o n s t r a i nt ; a “ C ” i n di cat e s t h a t p l ans a r e b e i ng p r o gr e s s e d t o d e a l wi th t h e c o n st r ai n t ; a n

“ F” m e a n s t h a t f ur t h er i n v e s t i g a ti o n i s r e q ui r e d b e f o r e a s olut i o n is s e l ec t e d . T h e n um e r ic al

s u f f i x e s s erve t o u n iq u el y i d e nt i f y t he c o n st ra i nts f or r e f er e nc e p ur p o se s .


8-3

8.2 OPPORTUNITIES FOR NEW DEMAND

“ Op p o rt u n i ty ” r e l at e s to w h er e th er e i s or wi l l b e c a paci ty f o r gr e at er u s e o f the g r i d

w i th o ut th e n e e d f o r f ur t h er r e i n f or ce m e n t s . H ow e v er , i f a d e v el o p er ch o o s e s t o con n e c t a

demand in an area that requi res re inforc ement , the TSO wi l l p rogress re levant gr id

d e v el o p m e nt s . D e m a n d d e v el o p er s s h o ul d c onsul t th e TSO ear l y i n th ei r dev el opment

p r o c es s t o ex pl o r e o pt i ons r e l at i ng t o t h ei r p roposal thus enabl ing t imely deci s i on ma king .

As a g ener al r u l e , opport uni t y at a par t i c ul ar s t at i on w oul d tend t o r educe over th e cour se

o f the seven years covered by the T ransmissi on Forecast Stat ement (TFS) as normal demand

g r ow t h u s e s u p a v a i l a ble c a p a ci t y . H o w ev e r , in many cases demand opportuni t ies improve

in later years as a resul t o f p l anned network or generat ion developments .

In 2010 t h er e w i l l be op p ort uni t i es f or a ddi t i ona l l arg e dema nd a t 20 of t h e 29 110 kV

s t a t i o n s ex ami n e d a n d in 2 0 1 6 t h er e wi l l b e op por t u ni t i e s a t a l l 2 9 s ta t i on s .

Opportuni t ies for incr eased demands are spread around the country . In general , indi v idual

demands up to 10 MW can be connected to most o f the other s tat ions on the gr id . An

addi t ional demand of 10 MW or more, ov er and above forecast demand, repr esents a

s igni f icant increase for most locat ions. To p ut th is i n con t e xt , a dem a n d o f 10 M W

r ep res ent s th e c ons umpti on of a t yp ic a l ph ar ma ceut ic al p l a nt .

F igure 8-2 i l lust rates the opportuni t ies for dema nd in 2013 and 2016. The graphics show

t h at th e re wi l l b e s i g ni f ic a n t d e m a n d o p p o r t u ni t ie s i n m o s t pa r t s of th e cou n t r y th r oug h o ut

the seven-year per iod to 2016.

I t sh oul d be not ed th at demand opport uni t y is tested for each s tat ion on an indi v idual

b a s i s . A s s uc h , t h e o p p or t u n i t i e s p r es e n t e d a re not cumulat i ve i .e . , i f new demand connects

in an ar ea that is shown to have opportuni ty th ey wi l l us e up s ome or a l l of th e av a i l a bl e

capaci ty in that ar ea.


8-4

<10 MW<10 MW

<10 MW<10 MW

F igure 8-2 Capabi l i ty for New Dema nd in 2013 and 2016

8.3 IMPACT OF CHANGES SINCE THE DATA FREEZE

S ince the begi n ni n g of Ju ly 2 009, a number o f developments have occurred that could

impa ct on th e r esul ts in T able 8-1 . The pl anned uprat ing of the Cahi r -Doon 110 kV c i rc u i t

a nd the pr oposed c on n ect i on o f a 98 MW OCGT at Cahi r should improv e demand opportuni ty

a t Cahi r .

8.4 HOW TO USE THE INFORMATION FOR DEMAND

Al though not ever y s tat ion was consider ed, the resul ts pr esented can be regarded as a

g u i de t o o pp o r t u ni t i e s a t ot h er st at i o n s i n t h e s a m e ar e a . T h o s e c o n si d e r i ng d ev el o p m e n t

o f a s igni f i can t d eman d i n the Republ ic o f I re l a nd s h o ul d t a ke t h e f o l l o wi n g a p p r o a ch f o r a n

indicat ion of whether the i r demand is l ikel y to be ac c ommodat ed wi th out th e need f or

a d d i t i o n al re i n f or c e m e nt s t ha t c o ul d p otent i a l l y de l a y th ei r connect ion.

Th e f i rs t s t ep i s t o c onsul t th e maps i n Append ix A to f ind the nearest t ransmissi on s tat ion

to the proposed d ev elopmen t an d where d i f ferent , the near est s tat ion for which opportuni ty

has been assessed. The ant ic ipated demand grow th at th e re l ev ant s t at ion c an be deduc ed

f rom the demand forecasts presented in Appendix C . The gr id is be ing pl anned to meet th is

l ev e l o f d em a n d i n cr e as e . H ow ev e r , i f t h e p rop o s e d n ew d e m a n d is fa r g r ea t er th a n t h e

a n n u a l f or ec a s t i n c r e a se t h e p ot e nt i a l d ev el o per s h o ul d ch e c k t h e op p o r t u n i t y a t t h e

2013 2016


8-5

nearest 110 kV s tat ion presented in Table 8- 1 i n t h i s cha p t er . T h e p o t e n t i a l d ev el o p e r

s hould the n chec k the assump t i on s i n Chapters 2 t o 4 o n w h i ch t h e s e r e s ul t s a r e b a s e d ,

a n d c o n si d er t h e i m p a ct o f ch a ng e s to th e n e t wo rk s i n c e th e ana l y si s w a s c a rr i e d o ut .

T o i l l u s t r at e t h i s a p p r oac h , t h e f o l l o w i ng i s an example o f how a developer p lanning t o

connect a new larg e dema nd of 12 MW (about 13 MVA) near Cast lebar in 2010 might use the

TFS. The maps in Appendix A show that the nearest 110 kV s tat ion is Cast lebar s tat ion.

Appendix C shows that the dema nd at Cast leba r wi l l b e abo u t 3 4 . 4 M W at wi n te r p e a k

2010/11 . Th is is forecast to grow by 2 .3 MW between 2010 and 2013 i .e . , by less than 1 M W

p e r a n n u m . T h e p r op os e d 1 2 M W i s f ar g r ea t e r t ha n th e a n n u al for e c as t i n c re a s e . I t

t h er e f or e r ep r e s e nt s a s t e p c h a ng e i n t h e d e ma nd at Cast lebar i .e . , the type o f increase

t h at i s th e sub j e ct of t h e t r a n s f er c a pa b i l i t y a na l ys i s p re s e n t ed i n th is c hap t e r .

The re s ul ts for Cast lebar i n Table 8-1 show that the opportuni ty for incr eased dema nd is

l e s s th a n 10 MW i n 2 01 0 . T h e t a ble d i r e ct s t he p o t e nt ia l d e v el o p er to c o n st r ai n t P 1 i n

A p p e n d ix F for a d d i t i o nal i n f or m at i on o n t h e c o ns t r ai n t a n d th e pl a n s th at t he T S O h av e i n

p lac e to addr ess the cons t r ai n t . T able F -1 in Ap pen d i x F sh ow s t h a t p ot en t i a l o v e r l o adi n g o f

the Ath l one-Shannonbr idg e 110 kV l i ne is responsi bl e f or l i mi t i ng the opport uni t y . Th e

ove r l oad occur s un der summer p eak t r ip -mai nte n a n c e c o ndi t i o n s . C api t a l p r oj e ct s C P 2 6 1

and CP552, which entai ls const ruct ion o f a second Athl one-Shannonbr idg e 110 kV l ine and

a n u p r a t e o f t h e e x i st i ng A t hl o n e - Sh an n o n b r i dge 1 1 0 k V l i n e , h av e b e e n i n i t i a ted b y t he T S O

to re l ieve the constr ai nt . Deta i l ed informat ion on capi ta l pro jects CP 261 and CP552 can be

f o u n d i n A pp e n d i x B . F ol lo wi ng c o mp l et i o n o f t h e s e pr o j ec t s t o w ar d s t h e e n d o f 2 0 1 2 t h e

opportuni ty a t Cast lebar increases to 30 MW in 2013. The opportuni ty decreases to 20 MW

by 2016 as a resul t o f normal demand gr owth in the area. Th is indi cates th at th e network is

l i ke l y t o b e c a p a bl e o f con n e c t i ng and s u p pl y i ng t h e pr o p ose d d e m a n d onc e c a pi t a l p r o j e c t s

CP261 and CP 552 have been ful ly implemented.

maPs and schematicsdiaGramsA.1 network maps

A.2 short bus codes

A.3 schematic network diagrams

APPENDIX A


A-1

APPENDIX A MAPS AND SCHEMATIC DIAGRAMS

Appendix A contai ns geographica l maps and schemat ic di ag rams of the gr id . Geograph ical

maps ar e presented i l lust rat ing the gr id as i t ex ists a t the beginning Ju ly of 2009 and as

p lanned for 2016. These maps are a lso inc luded in A3 format in Appendix I for greater

l eg i bi l i t y . Th e sc hem a t ic d ia gr a m s rep r e s e nt t h e gr id as p lanned at the end of 2009, 2013

and 2016.

A.1 NETWORK MAPS

T h i s s ec t i o n i n c l u d e s tw o n e t wo r k m ap s :

• F igure A-1 is a map of the ex ist ing gr id as a t Ju ly 01 s t 20 0 9;

• F igure A-2 is a map of the ex is t ing gr id inc l u di ng p l a n n e d d ev e l o p m e nt s as a t D e c e m be r

3 1 s t 2016.

NORTHERNIRELAND

NORTHERNIRELAND

LEGEND400 kV Lines220 kV Lines110 kV Lines

400 kV Stations220 kV Stations110 kV Stations

400 kV Cables220 kV Cables110 kV Cables

Hydro GenerationThermal Generation

Wind Generation

Transmission ConnectedGeneration

Planned Transmission System400 kV, 220 kV and 110 kV

As at July 2009LEGEND

400 kV Lines220 kV Lines110 kV Lines



Hydro GenerationThermal GenerationPumped Storage GenerationWind Generation


COBH

CORK AREA

CARRICKMINESKILTEEL

COOKSTOWN

MILLTOWN

HAROLDSCROSS

RYEBROOK

FINGLAS

INCHICORE

MACETOWN

BLACKROCK

GRIFFINRATH

MAYNOOTH

McDERMOTTRINAWADEWOLFE TONE

CITYWEST

CABRA

GRANGECASTLE

HUNTSTOWN

KILMORECOLLEGE

PARK

NANGOR

WOODLAND

GLASMORE

CORDUFF

GRANGE

NORTH WALL

SHELLYBANKS

IRISHTOWN

ARTANE

TANEY

Figure A - 1

RINGSEND

POTTERYROAD

CENTRALPARK

PELLETSTOWN

DARDISTOWN

CROMCASTLE

FRANCIS ST.

NORTH QUAYS

MISERY HILLPOOLBEG

KILTOY

CATHALEEN'SFALL CLIFF

BINBANE

TO STRABANE

GOLAGH

LETTERKENNY

DRUMKEEN

MEENTYCAT

SORNEHILL

TRILLICK

DRYBRIDGE

LISDRUM

LOUTH

DUNDALK

MEATHHILL

MULLAGHARLIN

NAVAN

275kV

TO TANDRAGEE

SLIGO

TAWNAGHMORE

MOY

CASTLEBAR

RICHMOND

CARRICK-ON-

SHANNON

BELLACORICK

TO ENNISKILLEN

GILRA

GORTAWEE

ARIGNA

TONROE

CORRACLASSYCUNGHILL

CORDERRY

SRANANAGH

FLAGFORD

SHANKILL

ARVA

RATRUSSAN

ENNIS

DALLOW

PORTLAOISE

CRANE

CARLOW

KILKENNY

THURLES

CAHIRDOON

ANNER

BALLYDINE

MALLOW

CHARLEVILLE

RATHKEALE

TARBERT

BUTLERSTOWN

DUNGARVAN

BLAKE

TULLABRACK

MUNGRETMONETEEN

FASSAROE

POLLAPHUCA

IKERRIN

LISHEEN

OUGHTRAGH

TRALEE

DUNFIRTH

KILLOTERAN

KILLONAN

RINAWADE

STRATFORDBALLYBEG

TIPPERARY

GLENLARA

ATHY

PROSPECT

MONREAD

TRIEN

DRUMLINE

AHANE

ARDNACRUSHA

LIMERICK

CASTLEFARM

SEALROCK

WATERFORD

TYNAGH

CLAHANE

DERRYBRIEN

AGANNYGAL

AUGHINISH

BOOLTIAGH

WEXFORD

KILTEEL

BALLYWATER

GREAT ISLAND

CULLENAGH

TURLOUGHHILL

MAYNOOTH

INCHICORE

CARRICKMINES

SEEDUBLINAREA

NORTH WALL

POOLBEGSHELLYBANKS

IRISHTOWN

OLDSTREET

FINGLAS

DUNSTOWNBARODA

NEWBRIDGE

HUNTSTOWN

MONEYPOINT

KELLIS

ARKLOW

PLATIN

KNOCKUMBER

GORMAN

BALTRASNA

GLASMORE

CORDUFF

WOODLAND

ATHLONE

CASHLA

GALWAY

LANESBORO

THORNSBERRY

CLOON

SOMERSET

CUSHALING

DALTON

DERRYIRON

SHANNONBRIDGE

KINNEGAD

MULLINGAR

BANDON

DUNMANWAY

MACROOM

BRINNY

KNOCKRAHA

KILBARRY

RAFFEEN

AGHADA

MARINA

CARRIGADROHIDCOOLROE

TRABEG

BALLYLICKEY

CLONKEEN

COOMAGEARLAHY

GARROW

GLANLEEINNISCARRA

SEECORKAREA

CLASHAVOON

BARRYMOREKNOCKEARAGH

LOUGHMAHON

CORKHARBOUR

AGHADA

WHITEGATE

MIDLETON

KNOCKRAHA

OLDCOURT

CASTLEVIEW

COW CROSS

LONGPOINT

BARNAHELYRAFFEEN

RINGASKIDDY

DUBLIN AREA

KILBARRY

MARINA

LIBERTYSTREET

TRABEGCITYCORK

SHELTONABBEY

NORTHERNIRELAND

NORTHERNIRELAND





Wind Generation









COBH

CORK AREA

CARRICKMINESKILTEEL

COOKSTOWN

MILLTOWN

HAROLDSCROSS

RYEBROOK

FINGLAS

INCHICORE

MACETOWN

BLACKROCK

GRIFFINRATH

MAYNOOTH


CITYWEST

CABRA

GRANGECASTLE

HUNTSTOWN

KILMORECOLLEGE

PARK

NANGOR

WOODLAND

GLASMORE

CORDUFF

GRANGE

NORTH WALL

SHELLYBANKS

IRISHTOWN

ARTANE

TANEY

Figure A - 1

RINGSEND

POTTERYROAD

CENTRALPARK

PELLETSTOWN

KILMAHUD

FINNSTOWNADAMSTOWN

BALGRIFFINDARDISTOWN

POPPINTREE

CROMCASTLE

CHERRYWOOD

HEUSTON SQUARE FRANCIS ST.

NORTH QUAYS

TRINITY

MISERY HILLPOOLBEG

KILTOY


BINBANE

TO STRABANE

GOLAGH

LETTERKENNY

DRUMKEEN

MEENTYCAT

TIEVEBRACK

BUNBEG

SORNEHILL

TRILLICK

DRYBRIDGE

LISDRUM

LOUTH

DUNDALK

MEATHHILL

MULLAGHARLIN

NAVAN

275kV

TO TANDRAGEE

TO TURLEENAN

MID CAVAN

SLIGO

TAWNAGHMORE

MOY

CASTLEBAR

RICHMOND

CARRICK-ON-

SHANNON

BELLACORICK

TO ENNISKILLEN

GILRA

GORTAWEE

ARIGNA

TONROE

CORRACLASSYCUNGHILL

CORDERRY

SRANANAGH

FLAGFORD

CARROWBEG

GARVAGH

GLENREE

SHANKILL

ARVA

RATRUSSAN

ENNIS

DALLOW

PORTLAOISE

CRANE

CARLOW

KILKENNY

THURLES

CAHIRDOON

ANNER

BALLYDINE

MALLOW

CHARLEVILLE

RATHKEALE

TARBERT

BUTLERSTOWN

DUNGARVAN

BLAKE

TULLABRACK

MUNGRETMONETEEN

FASSAROE

POLLAPHUCA

IKERRIN

LISHEEN

OUGHTRAGH

TRALEE

DUNFIRTH

KILLOTERAN

KILLONAN

RINAWADE

STRATFORDBALLYBEG

TIPPERARY

GLENLARA

BANOGE

ATHY

PROSPECT

NENAGH

MONREAD

TRIEN

BALLYCUMMIN

DRUMLINE

AHANE

ARDNACRUSHA

LIMERICK

CASTLEFARM

SEALROCK

WATERFORD

TYNAGH

BALLYRAGGET

CAUTEEN

CASTLEDOCKRILL

CHERRYWOOD

SINGLAND

ATHEA

CLAHANE

DERRYBRIEN

AGANNYGAL

AUGHINISH

BOOLTIAGH

WEXFORD

KILTEEL

BALLYWATER

GREAT ISLAND

CULLENAGH

TURLOUGHHILL

BALGRIFFIN

MAYNOOTH

INCHICORE

CARRICKMINES

SEEDUBLINAREA

NORTH WALL

POOLBEGSHELLYBANKS

IRISHTOWN

OLDSTREET

FINGLAS

DUNSTOWN

FINNSTOWN

BARODANEWBRIDGE

HUNTSTOWN

MONEYPOINT

KELLIS

ARKLOW

LODGEWOOD

LAOIS

PLATIN

KNOCKUMBER

STEVENSTOWN

GORMAN

BALTRASNA

GLASMORE

CORDUFF

WOODLAND

ATHLONE

CASHLA

GALWAY

LANESBORO

THORNSBERRY

CLOON

SOMERSET

CUSHALING

DALTON

SCREEB

SALTHILL

DERRYIRON

SHANNONBRIDGE

KINNEGAD

MULLINGAR

BANDON

DUNMANWAY

MACROOM

BRINNY

KNOCKRAHA

KILBARRY

RAFFEEN

AGHADA

MARINA


TRABEG

BALLYLICKEY

CLONKEEN

COOMAGEARLAHY

GARROW

GLANLEE

GLANAGOW

INNISCARRA

SEECORKAREA

CLASHAVOON


LOUGHMAHON

CORKHARBOUR

AGHADA

WHITEGATE

MIDLETON

KNOCKRAHA

OLDCOURT

CASTLEVIEW

COW CROSS

LONGPOINT

GLANAGOW

BARNAHELYRAFFEEN

RINGASKIDDY

DUBLIN AREA

MUINGNAMINNANE

KNOCKANURE

KISHKEAM

CORDAL

KNOCKACUMMER

KNOCKNAGASHEL

BALLYVOUSKILL

BOGGERAGH

KILPADDOGERALAPPANE

BRACKLONE

NORE

HARTNETT S’SCROSS

KEELDERRY

DROMADA

KILBARRY

MARINA

LIBERTYSTREET

TRABEGCITYCORK

As at December 2016

Figure A - 2

EASTWEST HVDC INTERCONNECTOR

MULREAVY

SHELTONABBEY

BALLAKELLY


A-4

A.2 SHORT BUS CODES

T h e f o l l ow i ng t a bl e a ss oc i at e s f u l l s t a t i o n n a m es w i th th e two o r t hr e e l et t er c o d e s use d i n

t h e s ch e m at i c d i agr a m s i n S e c t i o n A . 3 , i n th e t ab l e s i n A p p en d i c e s B a n d C , a n d t h e p o w e r

f l ow di ag r am s i n A p p e ndi x H . N a m es a n d c o d es f o r f ut u r e st a t i o n s , h igh l ig ht e d i n y e l l o w ,

a r e t e n t at i v e a n d m a y c h a ng e . I n p a r t i c ul ar “ M i d - C av a n” a n d “ La o i s” a r e h ol d i ng n a m e s

u n t i l t he s i tes f or th e s ta t i o ns ar e con f i r m ed .

S t a t i o n s i n N o r th e r n I r e l a n d th at ar e d i r e ct l y -co n n e c t e d t o s t a t i o n s i n t h e R e p u bl i c o f

I re l and are inc luded in th is table and marked wi th a * symbol .

Table A-1 Short Bus Codes

Short Bus Code

Fu l l Name Shor t Bus Code

Fu l l Name Shor t Bus Code

Fu l l Name

AA Ardnacrusha BK Bellacorick CHA Charleville

AD Aghada BLI Ballylickey CHE Cherrywood

ADM Adamstown BLK Blake CKM Carrickmines

AGL Agannygal BOG Banoge CKN Clonkeen

AHA Ahane BOL Booltiagh CL Cliff

ANR Anner BRA Bracklone CLA Clashavoon

ARI Arigna BRI Brinny CLH Clahane

ARK Arklow BRY Barnahely CLN Cloon

ARV Arva BUN Bunbeg CLW Carlow

ATE Athea BUT Butlerstown COL College Park

ATH Athlone BVK Ballyvouskill COR Corraclassy

ATY Athy BWR Ballywater COS Carrick-on-Shannon

AUG Aughinish BY Ballakelly COW Cow Cross

BAL Baltrasna CAH Cahir CRA Crane

BAN Bandon CBG Carrowbeg CRO Coolroe

BAR Barrymore CBR Castlebar CSH Cashla

BCM Ballycummin CD Carrigadrohid CTN Cauteen

BDA Baroda CDK Castledockrill CUL Cullenagh

BDN Ballydine CDL Cordal CUN Cunghill

BEG Ballybeg CDU Corduff CUS Cushaling

BGF Balgriffin CDY Corderry CVW Castleview

BGH Boggeragh CF Cathaleen's Fall DAL Dallow

BGT Ballyragget CFM Castlefarm DDK Dundalk

BIN Binbane CGL Coomagearlahy DER Derryiron


A-5

Table A-1 Short Bus Codes (cont inued)

S h o r t B u s Code

Fu l l Name S h o r t B u s Code


Fu l l Name

DFR Dunfirth HN Huntstown LSN Lisheen

DGN Dungarvan HTS Hartnett's Cross LWD Lodgewood

DLT Dalton IA Inniscarra MAC Macroom

DMY Dunmanway IKE Ikerrin MAL Mallow

DOO Doon INC Inchicore MAY Maynooth

DRM Drumkeen ISH Irishtown MCE Macetown

DRO Dromada KBY Kilbarry MCV Mid-Cavan

DRU Drumline KCR Knockacummer MEE Meentycat

DRY Drybridge KEE Keelderry MID Midleton

DSN Dunstown KER Knockearagh MLN Mullagharlin

DYN Derrybrien KIN Kinnegad MON Monread

EKN* Enniskillen KKM Kishkeam MOY Moy

ENN Ennis KKY Kilkenny MP Moneypoint

FAS Fassaroe KLM Kilmore MR Marina

FIN Finglas KLN Killonan MRY Mulreavy

FLA Flagford KLS Kellis MTH Meath Hill

FNT Finnstown KNG Knocknagashel MTN Moneteen

GAE Glanlee KNR Knockanure MUL Mullingar

GAL Galway KPG Kilpaddoge MUN Mungret

GAR Garvagh KRA Knockraha MUI Muingnaminnane

GCA Grange Castle KTL Kilteel NAN Nangor

GGO Glanagow KTN Killoteran NAV Navan

GI Great Island KTY Kiltoy NEN Nenagh

GIL Gilra KUD Kilmahud NEW Newbridge

GLA Glasmore KUR Knockumber NO Nore

GLE Glenlara LA Lanesboro NW North Wall

GLR Glenree LET Letterkenny OLD Oldcourt

GOL Golagh LIB Liberty Street OST Oldstreet

GOR Gorman LIM Limerick OUG Oughtragh

GRA Grange LIS Lisdrum PA Pollaphuca

GRI Griffinrath LOU Louth PB Poolbeg

GRO Garrow LPT Longpoint PLA Platin

GWE Gortawee LSE Laois PLS Portlaoise


A-6

Table A-1 Short Bus Codes (cont inued)

S h o r t B u s Code



Fu l l Name

PRO Prospect SK Sealrock THU Thurles

RAF Raffeen SKL Shankill TIP Tipperary

RAL Ralapanne SLI Sligo TIV Tievebrack

RAT Rathkeale SNG Singland TLK Trillick

RIC Richmond SOM Somerset TON Tonroe

RNW Rinawade SOR Sorne Hill TRI Trien

RRU Ratrussan SRA Srananagh TRL Tralee

RSY Ringaskiddy STR Stratford TSB Thornsberry

RYB Ryebrook SVN Stevenstown TLE* Turleenan

SAL Salthill TAN* Tandragee TYN Tynagh

SBN* Strabane TAW Tawnaghmore WAT Waterford

SCR Screeb TB Tarbert WEX Wexford

SH Shannonbridge TBG Trabeg WHI Whitegate

SHE Shelton Abbey TBK Tullabrack WMD West Midland

SHL Shellybanks TH Turlough Hill WOO Woodland

A.3 SCHEMATIC NETWORK DIAGRAMS

Schemat ic d i ag rams are inc l uded to ass is t users in understanding the network and in the

i d e n t i f i c at ion o f th e ch ang e s o ut l i n ed i n A p p en di x B . L i n e s , c a b l es , t r a ns f o r m er s , s t a t i o n

busbars and react ive compensat ion dev ices ar e i l l u st r at e d i n t h e di ag ra m s . T h e t yp e o f

g e n e r a t i o n ( t h er m al , w i nd o r h y d r o ) a t a s t at ion is a l so d isplayed. Tabl e A-2 indicates the

d iag ram conv ent ions.

T h e s ch e m at i c di ag r a m for 2 0 0 9 hi gh l ig ht s t h e d e v el o p m e nts d u e t o be c o m p l e t e d in 2 0 0 9 .

T h e d i agr a m f o r 2 0 1 0 dis p l a ys d e vel o p m e n t s d ue f o r c o mp l et i o n i n 2 0 1 0. T h e 2 0 1 3 di ag r a m

highl ights developments expected to be completed between 2010 and the end of 2013 whi le

the 2016 di ag ram highl igh ts developments due to be completed between 2013 and the end

of 2016.

In a l l d iag rams b l ue shading r e pr e s ent s a n e w d ev el o p m e n t, p i n k s h a d i ng denotes a c i rcu i t

u pra t ing , y e l l o w s h a d i ng i n di ca t e s t h e l oc a t i o ns o f c o n v e nt i o n al g e n era t o rs a n d o r a n g e

s h a d i n g i n dic a t e s t h e l o ca t i o ns of w in d g e n er at o rs .


A-7

Tabl e A-2 Schemat ic Legend

Symbol Networ k E lement Repr esented

4 0 0 kV c i r c ui t

2 7 5 kV c i rcui t

2 2 0 k V c i r c ui t

110 kV c i rcu i t

Busbar

B u s b ar w i t h t h er m al g e ner a t i o n

B u s b ar w i t h w i n d g e n er at i o n

B u s b ar w i t h t h er m al a n d w i n d g e n er at i o n

B u s b ar w i t h h y d r o g e n e ra t i o n

C a p a ci t or

S tat ic var compensator (SVC)

R e a c t or

Auto- t ransformer

Double-w ound t ransfor mer

P ha s e s hi f t in g t r a ns f o r me r

Spl i t -busbar

N o r m a l l y o pe n c i r cu i t

NONO


A-8

F ig u r e A -3 Sc h e m at ic D iag r a m o f th e E x is t i n g a n d P l a n n e d G r id a t E n d o f 20 0 9

BDN

MTH

Tandragee (NI)

Strabane (NI)

SKL

CLN

TBK

DRU

SOM

RIC

TSB

ATH

LISDDK

DRY

DGN

DOO

DSN

COW

RAT

KLN AHA

MAL

TBG

THU

CAH

BAR

BK

LA

IA

GI

SH

MCE

CLCF

GIL

BAN

Enniskillen (NI)

DAL

DMY

MLN

KUR

LIM

DFR

KLS

CRO

ARI

GAL

CBR

CVW

IKE

ANR

PA

CLW

WOO

BRY

CFM MUN

ISH

FIN

KLS

ADRAF

OST

CUL

STR

DLT

TIP

SLI

BEG

TON

COL

BLI

AGL

DYN

DER

RE

TAW

BRI

OLD

WHI

CGL

SK

CDY

ATY

GOR

CD

TYN

SRA

MON

RYB

GRI

MAY

SHL

DSN

BLK

NO

NAN

NW

SH

LIB

FLA

BUT

GI

GOL

LET

KTY TLK

MEE DRM

PB

CUL

CUL

HN

MP

GAE

RRU

CUS

SOR

BDA

MAC

AD

CHA

LPT

GGO

GRV

SNG

NAV

CRAWEX

BWR

ADM

RSY

KRA

FAS

RAF WAT

KTN

ARK

CKM

GLA

FIN

CDUWOO

INC

TH

LOU

ARV

GWECOR

FLA

CSH

PRO

KRA

BIN

NEW

AA

KTL

BGH

GOR

PLS

KLN

CSH

MAY

MTN GCA

MUL

KIN RNW

AUG

COS

KKY

CUNMOY

PLA BAL

CDU

CLH

CLA

TB

TRL

KER

CLA

TB

TRI

MID

DRO

GLE

CKN

MR

INC

MP

BOL

CKM

ARK SHE

LOU

GROKBY

OUG

ENN

LSN


A-9

F ig u r e A - 4 Sc h e m at ic D iag r a m o f th e E x is t i n g a n d P l a n n e d G r id a t E n d o f 201 0

BDN

MTH

Tandragee (NI)

Strabane (NI)

SKL

CLN

TBK

DRU

SOM

RIC

TSB

ATH

LISDDK

DRY

DGN

DOO

DSN

COW

RAT

KLN AHA

MAL

TBG

THU

CAH

BAR

BK

LA

IA

GI

SH

MCE

CLCF

GIL

BAN

Enniskillen (NI)

DAL

DMY

MLN

KUR

LIM

DFR

KLS

CRO

ARI

GAL

CBR

CVW

IKE

ANR

PA

CLW

WOO

BRY

CFM MUN

ISH

FIN

KLS

ADRAF

OST

CUL

STR

DLT

TIP

SLI

BEG

TON

COL

BLI

AGL

DYN

DER

RE

TAW

BRI

OLD

WHI

CGL

SK

CDYGOR

CD

TYN

NEN

SRA

MON

RYB

GRI

MAY

SHL

DSN

BLK

NO

NAN

NW

HTS

SH

LIB

FLA

BUT

GI

GOL

LET

KTY TLK

MEE DRM

PB

CUL

CUL

HN

MP

GAE

RRU

CUS

SOR

BDA

MAC

AD

CHA

LPT

GGO

GRV

SNG

KUD

NAVCBG

CRAWEX

BWR

BOG

CDK

ADM

SVN

RSY

KRA

KEE

FAS

ATY

RAF WAT

KTN

ARK

CKM

GLA

FIN

CDUWOO

INC

TH

LOU

ARV

GWECOR

FLA

CSH

PRO

KRA

BIN

NEW

AA

KTL

LDW

BGH

GOR

PLS

KLN

CSH

MAY

MTN GCA

MUL

KIN RNW

AUG

COS

KKY

CUNMOY

PLA BAL

CDU

ATE

CLH

CLA

TB

TRL

KER

CLA

TB

TRI

MID

DRO

GLE

CKN

MR

INC

MP

BOL

CKM

ARK

LOU

GRO

LDW

KBY

OUG

ENN

LSN


A-10


BDN

MTH

Tandragee (NI)

Strabane (NI)

SKL

CLN

TBK

DRU

SOM

RIC

TSB

ATH

LISDDK

DRY

DGN

DOO

DSN

COW

RAT

KLN AHA

MAL

TBG

THU

CAH

BAR

BK

LA

IA

GI

SH

MCE

CLCF

GIL

BAN

Enniskillen (NI)

DAL

DMY

MLN

KUR

LIM

DFR

KLS

CRO

ARI

GAL

CBR

CVW

IKE

ANR

PA

CLW

WOO

BRY

CFM MUN

ISH

FIN

KLS

ADRAF

OST

CUL

STR

DLT

TIP

SLI

BEG

TON

COL

BLI

AGL

DYN

DER

RE

TAW

BRI

OLD

WHI

CGL

SK

CDYGOR

CD

TYN

NEN

SRA

SRA

MON

RYB

GRI

MAY

SHL

DSN

BLK

NO

NAN

NW

HTS

SH

LIB

FLA

BUT

GI

GOL

LET

KTY TLK

MEE DRM

PB

CUL

CUL

HN

MP

GAE

RRU

CUS

SOR

BDA

MAC

AD

CHA

LPT

GGO

GRV

SNG

KUD

NAVCBG

BUN

SAL

Turleenan(NI)

CTN

CRAWEX

BWR

BOG

CDK

ADM

FNT

BGF

BGF

SVN

RSY

SCR

KRA

KEE

FAS

TIV

MRY

ATY

BCM

RAF WAT

KTN

ARK

CKM

GLA

FIN

CDUWOO

INC

FNT

TH

LOU

ARV

GWECOR

FLA

CSH

PRO

KRA

BIN

BRA NEW

AA

KTL

LDW

BGH

GOR

PLS

KLN

CSH

MAY

MTN

CHE

GCA

MCV

MCV

MUL

KIN RNW

AUG

COS

NOKKY

CUNMOY GLR

PLA BAL

CDU

RAL

ATE

CLH

CLA

TB

TRL

KER

CLA

TB

KPG

TRI

MID

DRO

GLE

CKN

MR

INC

MP

KPG

MP

BOL

CKM

ARK

LOU

BY

GRO

LDW

KBY

OUG

ENN

LSN


A-11


BDN

MTH

Tandragee (NI)

Strabane (NI)

SKL

CLN

TBK

DRU

SOM

RIC

TSB

ATH

LISDDK

DRY

DGN

DOO

DSN

COW

RAT

KLN AHA

MAL

TBG

THU

CAH

BAR

BK

LA

IA

GI

SH

MCE

CLCF

GIL

BAN

Enniskillen (NI)

DAL

DMY

MLN

KUR

LIM

DFR

KLS

CRO

ARI

GAL

CBR

CVW

IKE

ANR

PA

CLW

WOO

BRY

CFM MUN

ISH

FIN

KLS

ADRAF

OST

CUL

STR

DLT

TIP

SLI

BEG

TON

COL

BLI

AGL

DYN

DER

RE

TAW

BRI

OLD

WHI

CGL

SK

CDYGOR

CD

TYN

NEN

SRA

SRA

MON

RYB

GRI

MAY

SHL

DSN

BLK

NO

NAN

NW

HTS

SH

LIB

FLA

BUT

GI

GOL

LET

KTY TLK

MEE DRM

PB

CUL

CUL

HN

MP

GAE

RRU

CUS

SOR

BDA

MAC

AD

CHA

LPT

GGO

GRV

SNG

KUD

NAVCBG

BUN

SAL

Turleenan(NI)

CTN

BGT

CRAWEX

BWR

BOG

CDK

ADM

FNT

BGF

BGF

SVN

RSY

SCR

LSE

KRA

KEE

FAS

TIV

MRY

ATY

BCM

RAF WAT

KTN

ARK

CKM

GLA

FIN

CDUWOO

INC

FNT

TH

LOU

ARV

GWECOR

FLA

CSH

PRO

KRA

BIN

BRA NEW

AA

KTL

LDW

BGH

GOR

PLS

KLN

CSH

MAY

MTN

CHE

GCA

MCV

MCV

MUL

KIN RNW

AUG

COS

NOKKY

CUNMOY GLR

PLA BAL

CDU

RAL

ATE

CLH

CLA

TB

TRL

KER

KNR

CLA

TB

KNG

KNR

KPG

TRI

MID

MUI

DRO

KKM KKM

CDL

KCRGLE

BVK

CKN

MR

LSE INC

MP

KPG

MP

BOL

CKM

ARK

LOU

BY

GRO

BVK

LDW

KBY

OUG

ENN

LSN

network characteristicsB.1 characteristics of the existing network

B.2 changes in network characteristics

APPENDIX B


B-1

APPENDIX B NETWORK CHARACTERISTICS

This appendix pr esents detai ls of the phys ic a l a n d e l ec t r i ca l c haracter is t ics o f the

t r a n s mi s si on s y s t e m i n t a b ul ar f orm. D at a f o r th e ex is t i ng s ys t e m i s p r es e n t e d f i rs t ,

fo l lowed by the data for p lanned developments .

The pl anne d d ev elop ments i nc lud e networ k re in for c e m e nt p r o j e c t s t h at h av e b e e n se l e c t e d

by the TSO, and developments necessary to connect new generat ion and demands to the

g r i d a s a t the b e gi n n i ng o f J u l y 2 0 0 9 .

R e a d e r s sh oul d r ef e r t o S e c t i o n 1 . 4 i n C h a pt e r 1 o f t h e m ai n t e x t t o o b ta i n i n f or m at i o n o n

p r o jec ts ap pr ov ed s i nc e Ju l y 2009 .

T h e f o l l ow i ng i s a l i s t of t a b le s i n Sec t ion B . 1 :

Ta bl e B -2 Cha r a ct er i st ic s o f Ex i st i ng 4 00 kV L i nes

Tab le B-3 Char acter i st i c s o f Ex i st ing Cross-Border 275 kV L ines

Tab le B-4 Char acter i st i c s o f Ex is t ing 220 kV L ines and Cabl es

Tabl e B -5 Char act er i st ic s o f Ex i st i ng 110 kV L i nes and Cabl es

Table B-6 Character ist ics o f Ex ist ing 400/220 kV G r id T ransfor mers


T a b l e B - 8 C ha r a ct e r i st ic s o f E x i st i ng 2 2 0 / 1 1 0 k V G r i d T r a n sf or m e r s

T a b l e B - 9 C ha r a ct e r i st ic s o f E x i st i ng P o w er F l ow C o n t r ol l er

Table B-10 Ch aracter is t ics o f Ex i st i ng R e a ct iv e C om p e n s a t i o n

T h e f o l l ow i ng i s a l i s t of t a b le s i n Sec t ion B . 2 :

Table B-11 Ch anges in Ci rcui t Char acter is t ics Ex pected Af ter Ju ly 01 s t 2009

Tab le B-12 Chan ges i n Ci r c ui t Char acter is t ics Ex pected in 2010

T a b l e B - 13 Ch a n g e s i n Ci r c ui t C h ar a ct e r i s t i cs Ex pec t e d i n 2 0 11

Tab le B-14 Ch an ges i n Ci r c ui t Char acter is t ics Ex pected in 2012

Tab le B-15 Chan ges i n Ci r cui t Char acter is t ics Ex pected in 2013

Table B-16 Ch anges in Ci rcui t Char acter is t ics Ex pected Beyond 2013

Table B-17 Ch aracter is t ics o f Gr id Tr ansformers Ex pect ed in 2009

Table B-18 Character is t ics o f Gr id Tr ansformers Ex pect ed in 2010



B-2


Table B-21 Character is t ics o f Gr id Tr ans f o r m er s Ex p e ct e d i n 201 3

Tabl e B-22 Ch aracter is t ics o f G r id Tr ansformers Expected Beyond 2013

Table B-23 Ch aracter is t ics o f Reac t ive Compensat ion Expect ed in 2010

Table B-24 Ch aracter is t ics o f Reac t ive Compensat ion Expect ed in 2016

Tables B-2 to B-5 and Tables B-11 to B-16 inc lud e the rat ings for l ines and cabl es in MVA for

winter and summer reference temperature condi t ions at 1 per uni t (p .u . ) vo l tage. The h igher

a m b i e n t t e mp e r at u r e i n s u m m e r di c ta t e s a r e d uced t he r m al ra t i ng f or ove r h ea d l i n e s. T h e

r a t i n g i s t he m a x i m u m p e r m is s i bl e p o w e r th at t h e c i rc u i t ca n t r a n s p or t o n a c o n t i n u o u s

b as is . R efer en c e ambi ent temp er atures ar e :

• winter - 5°C;

• summer - 25°C.

The e l ec t r ica l charac ter is t ics o f the t ransmis sio n n e t w or k a t t h e th ree nomi nal v ol t ag e

leve ls are quoted in per uni t to an MVA base o f 100, and the appl icable re ferenc e vol tage as

r e f l e ct e d i n T a b l e B - 1 .

Table B-1 Nominal and Referenc e Vol tage Levels

Nomi nal Vol tag e Lev el Reference Vol tage

4 0 0 kV 3 8 0 k V

220 kV 220 kV

110 kV 110 kV

In some cases, ot her equipment associ at ed wi th a l ine or cable , such as cur rent

t r a n sf o r m er s, m a y h av e l o w e r r a t i ng s. H o w ev er , as t he s e ar e e a s i er t o u pr a t e o r ch a ng e o ut

than the l ine or cabl e , they are not ex pect ed to rest r ic t access to the gr id.

H istor ica l ly , a smal l number o f 110 kV s tat ions wer e c o n n e ct e d t o th e gr i d v i a a t e e i . e . , a n

u n - s w it ch e d c o n n e c t i o n i n t o a n e x ist i ng l i ne b e tw e e n t w o o th e r st a t i o n s. F o r t h e p u rp o s e s

of desc r ib ing the var ious sect i o n s o f l i n es i n t h e f o l l ow i ng t a b l es, t h e t e e poi n t i s

ident i f i ed by the na me of the teed 110 kV s tat ion wi th a suf f ix “T” added.


B-3

B.1 CHARACTERISTICS OF THE EXISTING NETWORK

Ta bl e B -2 Cha r a ct er i st ic s o f Ex i st i ng 4 00 kV L i nes

4 0 0 kV Ci r c ui t s Impedance p.u . on 100 MVA Rat ing (MVA)

F rom To No.

Length (km) R X B Summer W i n te r

DSN MP 1 208.5 0 .004 0.047 1 .049 1424 1713 MP OST 1 105.0 0 .002 0.023 0 .530 1424 1713 OST WOO 1 125.0 0 .002 0.028 0.631 1424 1713

Ta b le B-3 Char acter i st i c s o f Ex i st i ng Cr oss-Border 275 kV L ines

275 kV Ci rcui ts Impedance p.u . on 100 MVA Rat ing (MVA)

F rom To No.


LOU TAN 1 50.0 0 .002 0.021 0 .127 710 881 LOU TAN 2 50.0 0 .002 0.021 0 .127 710 881


B-4

Tab le B- 4 Char acter i st i c s o f Ex is t ing 220 kV L ines and Cabl es


F rom To No.


AD KRA 1 25 .6 0 .003 0.022 0.034 431 518 AD KRA 2 25.6 0 .003 0.022 0.034 431 518 AD LPT 1 1 .0 0 .000 0.000 0.027 593 593 ARK CKM 1 53 .3 0 .006 0.046 0.070 431 518 ARK GI 1 87 .8 0 .010 0 .076 0.115 431 518 CDU F IN 1 3 .7 0 .001 0 .003 0 .005 431 518 CDU F IN 2 3 .7 0 .001 0 .003 0 .005 431 518 C D U H N 1 4 . 5 0 . 0 0 0 0 . 0 0 2 0 . 1 2 3 5 9 3 5 9 3 CDU WOO 1 18.4 0 .002 0.016 0 .024 431 518 CDU WOO 2 17 .8 0 .002 0.016 0 .023 431 518 CKM DSN 1 41 .6 0 .005 0 .036 0.054 431 518 C K M I S H 1 1 1 . 7 0 . 0 0 0 0 . 0 0 5 0 . 3 2 0 5 9 3 5 9 3 CKM PB 1 14 .5 0 .001 0 .005 0 .618 267 267 CLA KRA 1 45 .0 0 .005 0 .039 0.059 431 518 CLA TB 1 97 .3 0 .011 0 .084 0.127 431 518 CSH FLA 1 88.1 0 .010 0 .076 0.115 431 518 CSH PRO 1 88.5 0 .010 0 .077 0 .116 431 518 CSH TYN 1 33.8 0 .004 0.029 0.044 431 518 CUL GI 1 23.0 0 .003 0 .020 0.030 229 438 CUL KRA 1 86.0 0 .010 0 .075 0 .113 431 518 DSN KLS 1 59.3 0 .007 0 .051 0 .077 431 518 DSN MAY 1 36.3 0 .004 0.032 0.048 431 518 DSN MAY 2 30.6 0 .004 0.027 0 .040 431 518 DSN TH 1 26.6 0 .003 0.022 0.144 351 351 F IN HN 1 1 .4 0 .000 0.001 0 .038 570 570 F IN NW 1 11 .9 0 .001 0 .004 0.680 332 332 F IN SHL 1 13 .4 0 .001 0 .005 0 .367 572 572 FLA LOU 1 110.1 0 .013 0 .095 0 .144 431 518 GI KLS 1 69.3 0 .008 0.060 0.091 431 518 GOR LOU 1 32.4 0 .004 0.028 0.042 431 518 GOR MAY 1 42.2 0 .005 0 .037 0 .055 431 518 INC ISH 1 11 0 .000 0.004 0.301 593 593 INC MAY 1 19 .1 0 .002 0.017 0 .025 431 518 INC MAY 2 19.1 0 .002 0.017 0 .025 431 518 INC PB 1 12 .5 0 .001 0 .004 0.504 267 267 INC PB 2 11 .3 0 .001 0 .003 0.722 351 351 ISH SHL 1 1 . 1 0 .000 0.001 0 .030 548 548 KLN KRA 1 82.4 0 .013 0 .073 0 .105 286 370 KLN SH 1 89.7 0 .014 0 .080 0.115 286 370 KLN TB 1 70.6 0 .008 0.061 0 .092 431 518 KRA RAF 1 23.4 0 .003 0 .020 0.031 431 518 LOU WOO 1 61 .2 0 .007 0 .053 0 .080 431 518 MAY SH 1 105.6 0 .017 0 .094 0.135 286 370 MAY TH 1 53 .1 0 .006 0.044 0.184 351 351 MAY WOO 1 22.3 0 .003 0 .020 0.030 431 518 MP PRO 1 12 .7 0 .001 0 .009 0.021 825 992 NW PB 1 4 .5 0 .000 0.001 0 .261 332 332


B-5

T a b l e B - 4 Cha r a ct e r i st i c s o f E x i st i ng 220 kV L ines and Cabl es (cont inued)


F rom To No.


OST TYN 1 14 .5 0 .002 0.013 0 .019 431 518 P B P B 1 … 0 . 0 0 0 0 . 0 3 7 … 4 5 0 4 5 0 PB SHL 1 0 .12 0 .000 0.001 0 .012 250 250 P R O T B 1 1 0 . 3 0 . 0 0 1 0 . 0 0 7 0 . 1 7 3 3 8 1 3 8 1

Tabl e B -5 Char act er i st ic s o f Ex i st i ng 110 kV L i nes and Cabl es

1 1 0 k V C i r c ui t s Impedance p.u . on 100 MVA Rat ing (MVA)

F rom To No.


AA D R U 1 18.4 0 .029 0.067 0 .006 107 126 AA ENN 1 33 .0 0 .051 0 .117 0 .011 107 126 AA KLN 1 9 . 4 0 .006 0.031 0 . 0 0 3 187 223 AA L I M 1 11 .7 0 .014 0 .038 0.012 107 126 A D W H I 1 3 . 1 0 .005 0 .011 0 .001 107 126 A G L DYN 1 8 .0 0 . 0 1 3 0 .028 0 . 0 0 3 107 126 A G L ENN 1 3 8. 2 0 .059 0 .131 0 .012 107 126 A G L S H 1 46.2 0 .072 0.159 0.015 107 126 A H A KLN 1 3 . 8 0 .004 0.012 0 .004 115 115 ANR D OO 1 2 .0 0 . 0 0 3 0.007 0 .001 107 126 ARI ARI T 1 0 .2 0 .000 0.001 0 .000 107 126 ARK B EG 1 21 .9 0 .010 0 .079 0 .007 1 3 7 164 ARK CRA 1 41 .8 0 .064 0 . 1 4 4 0 . 0 1 3 107 126 ARK S H E 1 2 .2 0 .004 0.008 0.001 3 4 57 ARK S H E 2 2 .2 0 .004 0.008 0.001 72 1 0 3 ARV COS 1 41 . 4 0 .064 0.142 0 . 0 1 3 107 126 ARV G W E 1 30. 6 0 . 0 3 7 0 . 1 0 3 0 .010 107 126 ARV NAV 1 60.6 0 .086 0.207 0 .020 107 126 ARV SKL 1 18.6 0 .029 0.065 0 .006 86 111 A T H LA 1 3 5 . 7 0 .054 0 . 1 2 3 0.012 107 126 A T H S H 1 21 .6 0 .022 0.072 0 .009 9 3 1 3 1 ATY ATY T 1 5 .5 0 .009 0.019 0 .002 107 126 ATY T P L S 1 21 .1 0 . 0 3 3 0 . 0 7 3 0 .007 107 126 ATY T CLW 1 19 .5 0 . 0 3 0 0.067 0 .006 107 126 A U G C F M 1 0 .7 0 .001 0 .002 0.001 96 96 A U G C F M 2 0 .7 0 .001 0 .002 0.001 96 96 A U G MTN 1 27 .5 0 .017 0 .089 0.010 187 223 A U G SK 3 1 .0 0 .001 0 .001 0 .006 120 120 A U G SK 4 1 .0 0 .001 0 .001 0 .006 120 120 A U G T B 1 3 4 . 0 0 .021 0 .111 0 .012 187 223 B A L CDU 1 16.8 0 .011 0 .055 0 .006 187 223 B A L DRY 1 20.0 0 . 0 1 3 0 .065 0 .007 187 223 BAN B RI 1 2 .6 0 .004 0.009 0.001 107 126 BAN B RI 2 2 .5 0 .004 0.009 0.001 107 126 BAN D M Y 1 25.9 0 .040 0.089 0.008 107 126 BAN RAF 1 26.9 0 .041 0 .091 0 .012 107 126 BAR BAR T 1 0 . 3 0 .001 0 .001 0 .000 107 126 B D A M O N 1 12.5 0 .012 0 .036 0.020 120 128


B-6

Table B-5 Character ist ics o f Ex ist ing 110 kV L ines and Cabl es (cont inued)


F rom To No.


B D A N E W 1 7 .9 0 .007 0 .020 0.019 120 128 B D N CU L 1 21 .8 0 .034 0.075 0 .007 107 126 B D N D OO 1 1 1 . 3 0 .018 0 . 0 3 9 0 .004 107 126 B EG C K M 1 3 2.3 0 .015 0 .116 0 .010 1 3 7 164 BIN CF 1 3 4 .3 0 . 0 5 3 0.118 0 .011 107 126 B K CB R 1 3 7 . 4 0 .058 0.128 0 . 0 1 3 107 126 B K M O Y 1 27 .2 0 .042 0.097 0 .009 107 126 B L I D M Y 1 27 .6 0 . 0 43 0 . 0 9 4 0.010 107 126 B L K BLK T 1 0 .5 0 .001 0 .002 0.000 1 3 7 164 B O L ENN 1 24.0 0 . 0 3 7 0 . 0 8 3 0.008 107 126 B O L TBK T 1 19 .6 0 .031 0 .067 0 .006 107 126 BR Y RAF 1 1 .7 0 . 0 0 3 0.006 0.001 72 1 0 3 BR Y RAF 2 1 .8 0 .002 0.006 0.001 107 126 B U T CU L 1 11 .6 0 .018 0 .040 0.004 107 126 B U T KTN 1 2 .7 0 .004 0.009 0.001 107 126 B W R CRA 1 21 .9 0 .011 0 . 0 3 0 0 . 1 3 7 116 116 C A H BAR T 1 44.2 0 .066 0.152 0 .014 107 126 C A H D OO 1 16.0 0 .025 0.055 0 .005 107 126 C A H T H U 1 3 9 . 0 0 .041 0 . 1 3 0 0 . 0 1 3 1 3 7 164 C A H T IP 1 27 .0 0 .042 0.093 0 .009 107 126 CB R CLN 1 57 .7 0 .090 0.198 0.020 107 126 CB R DLT 1 27 .8 0 . 0 43 0.096 0.009 107 126 CD K B Y 1 33.6 0 .052 0.116 0 .011 107 126 CD MAC 1 1 .0 0 .002 0.004 0.000 107 126 CDU MCE 1 4 .1 0 . 0 0 3 0.010 0.016 1 3 7 164 CDU M U L 1 7 3 .3 0 .088 0.237 0 .041 107 126 CDU P L A 1 3 7 . 0 0 . 0 2 3 0.120 0 . 0 1 3 187 223 CDU R Y B 1 18.5 0 .018 0 .060 0 . 0 2 3 111 128 CDY ARI T 1 17 .0 0 .0177 0 .057 0 .006 1 3 7 164 CDY SRA 1 12 .7 0 .015 0 . 0 43 0 .004 107 126 CF SRA 1 52.7 0 .071 0 .179 0 .017 107 126 CF SRA 2 49.2 0 .062 0.166 0.016 107 126 CF CL 1 5 .5 0 .006 0.018 0.002 1 3 7 164 CF COR 1 6 1 . 3 0 .064 0.205 0.021 107 126 CF D R M 1 51 .3 0 .077 0 .176 0 .017 107 126 CF G O L T 1 25.5 0 .040 0.088 0.008 107 126 CG L G A E 1 2 .0 0 .001 0 . 0 0 3 0.015 140 1 4 3 CHA G L E 1 3 0 . 0 0 .047 0 . 1 0 3 0 .010 107 126 CHA KLN 1 3 6 . 9 0 .057 0 .127 0 .012 72 1 0 3 CHA MAL 1 22.5 0 .035 0 .077 0 .007 72 1 0 3 C K M FAS 1 7 .5 0 .011 0 .026 0 . 0 0 3 107 126 C K M FAS 2 7 .5 0 .012 0 .026 0.002 107 126 CKN CG L 1 6 . 3 0 .004 0.021 0 .002 187 223 CKN KER 1 20.3 0 . 0 1 3 0 .066 0.007 187 223 CKN G RO 1 15 .8 0 .008 0.015 0 .157 120 120 CLA CKN 1 29.8 0 .019 0 .097 0 .011 187 223


B-7



F rom To No.


CLA MAC 1 5 .7 0 .004 0.018 0.002 187 223 C L H TRI 1 9 .0 0 .014 0 .031 0 . 0 0 3 107 126 C L H TRL 1 13 .5 0 .020 0.045 0.025 107 126 CLN LA 1 64.6 0 .075 0 .221 0 .022 107 126 CLW KLS 1 5 .4 0 .008 0.019 0 .002 107 126 CLW KLS 2 5 .3 0 .008 0.019 0 .002 107 126 CLW STR T 1 17 .6 0 .027 0 .061 0 .006 107 126 COL CDU 1 2 .3 0 .001 0 .004 0.020 140 1 4 3 COL F IN 1 4 . 9 0 . 0 0 3 0 . 0 1 3 0 . 0 3 7 120 141 COR EKN 1 27 .5 0 . 0 43 0.095 0 .009 107 126 COR G W E 1 10.9 0 .015 0 . 0 3 7 0 .004 107 126 COS ARI T 1 20.7 0 .022 0.069 0.007 120 128 COS FLA 1 3 . 4 0 .005 0.012 0 .001 107 126 COS FLA 2 3 .3 0 .005 0 .011 0 .001 107 126 C O W O L D 1 2 .3 0 .004 0.008 0.001 107 126 C O W O L D 2 2 .2 0 . 0 0 3 0.008 0.001 107 126 C O W RAF 1 6 .9 0 .010 0 .024 0 . 0 0 3 107 126 C O W W H I 1 17 .8 0 .027 0 .062 0.006 107 126 CRA W E X 1 21 .3 0 . 0 3 3 0 . 0 7 3 0 .007 72 1 0 3 C R O IA 1 2 .7 0 .004 0.010 0 .001 107 126 C R O K B Y 1 1 4 . 3 0 .022 0 . 0 4 9 0.005 107 126 C S H CLN 1 22.8 0 .036 0.078 0.007 107 126 C S H ENN 1 53 .6 0 . 0 8 3 0.185 0 .017 107 126 C S H G A L 1 13 .8 0 .021 0 .047 0 .004 107 126 C S H G A L 2 1 1 . 3 0 .018 0 . 0 3 9 0 .004 107 126 C S H G A L 3 1 1 . 3 0 .018 0 . 0 3 9 0 .004 107 126 C S H SOM T 1 4 4 . 9 0 .070 0.154 0 .014 107 126 CU L D G N 1 3 4 .3 0 . 0 5 3 0 .116 0 .016 107 126 CU L WAT 1 12 .5 0 .019 0 . 0 43 0.005 107 126 CU N M O Y 1 40.7 0 . 0 6 3 0 .140 0 . 0 1 3 107 126 CU N SL I 1 20.0 0 .031 0 .069 0.006 107 126 CU S BLK T 1 27 .4 0 .029 0.091 0 .009 1 3 7 164 CU S P L S 1 41 .8 0 . 0 4 4 0.140 0 .014 1 3 7 164 C V W C O W 1 17 .2 0 .025 0 .054 0.018 107 126 C V W KRA 1 7 .6 0 .012 0 .026 0.004 107 126 DAL DAL T 1 12 .2 0 .019 0 .042 0.004 107 126 D D K L O U 2 16.8 0 .026 0.058 0.005 107 126 D D K MLN 1 7 .5 0 .012 0 .026 0 . 0 0 3 107 126 DER K IN 1 15 .1 0 .012 0 .050 0.005 120 128 DER M A Y 1 4 3 . 0 0 .027 0 . 1 3 9 0.018 9 0 95 DER T S B 1 19 .7 0 .031 0 .068 0.006 107 126 DFR DFR T 1 0 .1 0 .000 0.000 0.000 107 126 D G N KRA 1 53 .7 0 .084 0.185 0 .017 107 126 DLT G A L 1 55 .1 0 .086 0.190 0.018 107 126 D M Y MAC 1 26.2 0 .041 0 .091 0 .008 107 126 D R M LET 1 8 .0 0 . 0 1 3 0 .028 0 . 0 0 3 107 126 D R M M E E 1 5 .0 0 .008 0.017 0 .002 107 126


B-8



F rom To No.


D R U ENN 1 17 .4 0 .027 0 .060 0.006 107 126 DRY G O R 1 19 .4 0 .029 0.067 0 .006 107 126 DRY L O U 1 3 1 . 9 0 .050 0.110 0 .010 107 126 DRY P L A 1 5 .3 0 .008 0.018 0.002 107 126 F IN G L A 1 14 .0 0 .022 0.048 0.005 107 126 F IN G L A 2 14.2 0 .022 0 . 0 4 9 0.005 107 126 F IN G RA 1 13 .2 0 .005 0.012 0 .236 119 119 F IN K L M 1 9 . 3 0 .005 0 .010 0.056 120 1 3 1 F IN MCE 1 7 .6 0 .008 0.025 0 .007 120 128 FLA G I L 1 10 .6 0 .017 0 . 0 3 7 0 . 0 0 3 107 126 FLA LA 1 30.6 0 .048 0.105 0 .010 107 126 FLA SL I 1 50.5 0 .079 0 .174 0 .016 107 126 FLA TON 1 3 2.3 0 .050 0.112 0 .010 107 126 G CA G RI T 1 8 .9 0 .009 0.029 0.006 111 1 4 3 G CA INC 1 8 .1 0 .008 0.025 0 .009 111 1 4 3 G CA INC 2 7 .8 0 .008 0 . 0 2 3 0 .010 111 1 4 3 G CA NAN 1 1 .8 0 .001 0 .002 0.011 120 120 G CA NAN 2 1 .7 0 .001 0 .002 0.011 120 1 3 1 G I KKY 1 49.2 0 .077 0 .169 0.016 107 126 G I WAT 1 11 .7 0 .008 0.038 0.004 1 3 7 164 G I WAT 2 12.9 0 .008 0.042 0.005 120 128 G I W E X 1 3 4 . 5 0 .054 0.119 0 .011 107 126 G O L G O L T 1 3 . 9 0 .006 0.014 0 .001 107 126 G O R NAV 1 5 .3 0 .008 0.019 0 .002 107 126 G O R NAV 2 6 . 3 0 .009 0.022 0.002 107 126 G O R P L A 1 19 .7 0 . 0 3 0 0.068 0.006 107 126 G RA K L M 1 5 .9 0 . 0 0 3 0.007 0 .036 120 120 G RI G RI T 1 1 .0 0 .002 0.004 0.000 107 126 G RI M A Y 1 2 .2 0 . 0 0 3 0 .009 0.001 107 126 IA MAC 1 18.1 0 .028 0 . 0 6 3 0.006 107 126 IKE IKE T 1 0 .2 0 .000 0.001 0 .000 9 3 1 3 1 K B Y KRA 1 11 .9 0 .014 0 .040 0.004 107 126 K B Y KRA 2 12.5 0 .018 0 . 0 43 0 .004 107 126 K B Y MAL 1 29.1 0 .045 0 .101 0 .009 72 1 0 3 K B Y M R 1 4 .0 0 .004 0 . 0 1 3 0 . 0 0 3 111 128 K B Y M R 2 4 .0 0 .004 0 . 0 1 3 0 . 0 0 3 111 128 KER OUG T 1 22.6 0 .014 0 .074 0.008 187 223 K IN DFR T 1 29.3 0 .021 0 .096 0.010 120 164 KLN L I M 1 9 .0 0 .014 0 .031 0 . 0 0 3 107 126 KLN L I M 2 11 .7 0 .018 0 .040 0.009 86 111 KLN T IP 1 41 .0 0 .064 0.141 0 . 0 1 3 107 126 KLS KKY 1 3 4 .3 0 . 0 5 3 0.118 0 .011 107 126 KRA BAR T 1 19 .4 0 .020 0.065 0 .007 1 3 7 164 KRA M I D 1 10.7 0 .017 0 . 0 3 7 0 .004 107 126 KTL KTL T 1 1 . 3 0 .002 0.005 0 .001 107 126 KTN WAT 1 3 . 4 0 .005 0.012 0 .001 107 126 KTY LET 1 4 . 9 0 .006 0.017 0 .002 107 126


B-9



F rom To No.


KUR NAV 1 6 .1 0 .010 0.021 0 .002 107 126 LA M U L 1 4 6 . 3 0 .072 0.160 0.015 107 126 LA R IC 1 14 .7 0 . 0 2 3 0.050 0.007 107 126 LA R IC 2 14 .7 0 . 0 2 3 0.051 0 .005 107 126 LET G O L T 1 3 8. 4 0 .058 0.132 0.012 107 126 LET SBN 1 24.0 0 . 0 3 7 0 . 0 8 3 0.008 107 126 LET TLK 1 3 4 . 7 0 .054 0.119 0 .011 107 126 L I B MR 1 2 .7 0 .001 0 . 0 0 3 0.017 100 100 L I B MR 2 2 .7 0 .002 0 . 0 0 3 0.017 120 120 L I M MTN 1 7 .5 0 .005 0.025 0 . 0 0 3 1 3 7 164 L I M RAT 1 29.1 0 . 0 4 4 0.101 0 .012 107 126 L IS L O U 1 4 0 . 4 0 . 0 6 3 0 . 1 3 9 0 . 0 1 3 107 126 L IS SKL 1 3 9 .3 0 .061 0 .135 0 . 0 1 3 107 126 L O U MLN 1 1 3 . 0 0 .020 0.045 0 .004 107 126 L O U M T H 1 15 .1 0 .024 0.052 0.005 107 126 L O U RRU 1 3 7 . 5 0 .058 0.129 0.012 107 126 LSN T H U 1 10 .4 0 .016 0 .036 0 . 0 0 3 107 126 M A Y BLK T 1 3 0 . 9 0 .032 0 . 1 0 3 0 .011 1 3 7 164 M A Y G RI T 1 2 .2 0 .002 0.007 0 .002 111 1 4 3 M A Y KTL T 1 19 .5 0 .020 0.065 0 .007 120 128 M A Y RNW 1 7 .1 0 .008 0.024 0.002 107 126 M A Y R Y B 1 8 .9 0 .009 0 . 0 3 0 0 . 0 0 3 120 128 M I D W H I 1 20.0 0 . 0 3 0 0.069 0.007 107 126 M O N KTL T 1 10 .1 0 .011 0 .034 0 .004 120 128 M O Y T A W 1 8 .4 0 . 0 1 3 0 .029 0 . 0 0 3 107 126 M O Y T A W 2 8.3 0 . 0 1 3 0 .029 0 . 0 0 3 107 126 M P TBK T 1 6 .6 0 .010 0 . 0 2 3 0.002 107 126 MR T B G 1 3 .3 0 .004 0.005 0 . 0 4 4 7 9 7 9 MR T B G 2 2 .9 0 .002 0 . 0 0 3 0.028 7 9 7 9 MTN M U N 1 0 .7 0 .001 0 . 0 0 3 0.000 107 126 MTN M U N 2 0 .7 0 .001 0 .002 0.000 107 126 N E W P L S 1 4 3 . 0 0 .055 0 .146 0 .014 107 126 O UG OUG T 1 11 .0 0 .017 0 .038 0.004 107 126 P A STR T 1 22.4 0 .035 0 .077 0 .007 107 126 P L S DAL T 1 54.7 0 .040 0.179 0 .019 72 1 0 3 RAF RSY 1 2 .1 0 . 0 0 3 0 .007 0 .001 72 1 0 3 RAF T B G 1 10.6 0 .016 0 .036 0.005 107 126 RAF T B G 2 9 .2 0 .014 0 .032 0 .004 107 126 RAT T B 1 33.6 0 .035 0 .112 0 .012 1 3 7 164 RNW DFR T 1 25 .9 0 .020 0.085 0 .009 107 126 RRU SKL 1 14 .5 0 . 0 2 3 0.050 0.005 107 126 S H DAL T 1 12 .0 0 .019 0 .041 0 .005 72 1 0 3 S H IKE T 1 53 .7 0 .056 0.179 0 .018 9 3 1 3 1 S H SOM T 1 13 .8 0 .021 0 .047 0 .006 107 126 SL I SRA 2 12.0 0 .019 0 .041 0 .004 107 126 SL I SRA 1 11 .1 0 .017 0 .038 0.004 107 126


B-10



F rom To No.


S O M SOM T 1 2 .0 0 . 0 0 3 0.007 0 .001 107 126 SOR TLK 1 4 . 4 0 .007 0.015 0 .002 107 126 STR STR T 1 2 .0 0 . 0 0 3 0.007 0 .001 107 126 T B TRI 1 20.5 0 .021 0 .069 0.007 120 128 T B TRL 1 42.0 0 . 0 6 3 0 .147 0 .014 107 126 TBK TBK T 1 2 .9 0 .005 0 .010 0 .001 107 126 T H U IKE T 1 25 .9 0 .027 0 .087 0 .009 9 3 1 3 1 TRL OUG T 1 1 1 . 3 0 .007 0 . 0 3 7 0 .004 187 223


Impedance p.u . on 100 MVA Vol tage Rat io Tapping Range Transfor mer

R a t i ng (MVA)

R X + -

D u nstown T4 2 01 500 0.000 0.032 1% 15% Moneypoint T4201 500 0.000 0 . 0 3 3 1% 15% Ol dst reet T4202 500 0.000 0.027 10% 7% Woodland T4201 500 0.000 0.032 1% 15% Woodl a nd T4 202 550 0 .000 0.018 N/A T o t a l 2 ,5 50


Impedance p .u . on 100 MVA Vol tage Rat io Tapping Range Transfor mer

R a t i ng (MVA)

R X + -

Louth AT1 300 0.001 0 .030 15% 15% Louth AT2 600 0.001 0 .015 15% 15% Louth AT3 300 0.001 0 .030 15% 15% Tota l 1 ,200


B-11

T a b l e B - 8 C ha r a ct e r i st ic s o f E x i st i ng 2 2 0 / 1 1 0 k V G r i d T r a n sf or m e r s


R a t i ng (MVA)

R X + -

Aghada T2102 125 0 .001 0 .124 10% 18% Arkl ow T2101 63 0 .007 0 .180 23% 19% Arkl ow T2102 125 0 .002 0.124 9% 18% Carr ickmines T2101 250 0.001 0 .065 9% 17% Carr ickmines T2102 250 0.001 0 .065 9% 17% Cashla T2101 1 250 0 .000 0.063 9% 18% Cash la T2102 250 0.000 0.063 9% 18% Cash la T2104 175 0 .002 0.133 22% 18% C las havoon T2101 125 0 .001 0 .124 9% 17% Corduf f T2101 250 0.001 0 .064 9% 17% Corduf f T2102 250 0.001 0 .061 9% 17% Cul lenagh T2101 250 0.001 0 .064 9% 18% F inglas T2101 250 0.001 0 .065 9% 18% F inglas T2102 250 0.001 0 .065 9% 18% F inglas T2103 250 0.001 0 .064 9% 17% F inglas T2104 250 0.001 0 .064 9% 17% F l agford T2101 125 0 .003 0.128 9% 18% F l agford T2102 125 0 .001 0 .133 9% 18% Gorman T2101 250 0 .001 0 .064 9% 18% Great Is land T2101 125 0 .003 0.133 9% 18% Great Is land T2102 125 0 .002 0.124 22% 18% Inch icore T2101 250 0.001 0 .056 9% 17% Inch icore T2102 250 0.001 0 .056 9% 17% Inch icore T2104 250 0.000 0.060 9% 18% Kel l is T2101 125 0 .001 0 .124 9% 18% Kel l is T2102 125 0 .001 0 .124 9% 18% K i l lonan T2101 63 0 .007 0 .245 22% 18% K i l lonan T2102 63 0 .010 0.247 22% 18% K i l lonan T2104 125 0 .001 0 .123 9% 18% Knockr ah a T2101 250 0.001 0 .065 9% 17% Knockr ah a T2102 250 0.001 0 .065 9% 17% Louth T2101 125 0 .002 0.133 22% 18% Louth T2102 125 0 .002 0.132 23% 18% Louth T2103 125 0 .002 0.132 22% 18% Louth T2104 250 0.001 0 .064 9% 17% Maynooth T2101 125 0 .002 0.134 22% 18% M a y n o ot h T21 0 2 1 1 250 0 .001 0 .064 9% 17% Maynooth T2103 125 0 .002 0.132 22% 18% Maynooth T2104 250 0.001 0 .064 9% 17% Poolbeg TF3 250 0.001 0 .059 8% 17% Poolbeg TF4 250 0.001 0 .061 8% 17% Raf feen T2101 1 1 250 0 .001 0 .064 9% 17% Raf feen T2102 250 0.000 0.056 9% 17%

1 T r a n s f o r m e r c a p a c i t y l i m i t e d t o 2 3 8 M V A a t 1 1 0 k V b y t h e 1 1 0 k V s w i t c h g e a r .


B-12

Table B-8 Character ist ics o f Ex ist ing 220/110 kV G r i d T r a n sf or m e r s ( c o nt in u e d )


R a t i ng (MVA)

R X + -

Shannonbr idge T2101 125 0 .006 0.124 9% 18% Shannonbr idge T2102 125 0 .001 0 .124 9% 18% Tarber t T2101 250 2 0 .001 0 .055 9% 17% Tarber t T2102 250 2 0 .001 0 .055 9% 17% T o t a l 8 , 9 8 9

T a b l e B - 9 C ha r a ct e r i st ic s o f E x i st i ng P o w er F l ow C o n t r ol l er

Impedance p.u . on 100 MVA

Phase Angle Range (e l ect r i ca l deg r ees ) Stat ion

R a t i ng (MVA)

C i r c ui t

R X + -

Car r ickmines 350 CKM-PB 220 kV 0 .000 0.029 15.3 15.3

Table B-10 Ch aracter is t ics o f Ex i st i ng R e a ct iv e C om p e n s a t i o n

M v ar Ca p a bi l i t y Stat ion B u s P la nt

G e nera t e Absorb

Ath lone ATH 110 2 Capaci tors ( 1 Mobi le ) 60 Bandon BAN 110 1 Capaci tor 15 Cah ir CAH 110 4 Capaci tors 60 C a r r i c k mi n es C K M 2 2 0 1 S h u nt R ea ct o r 1 0 0 Cashla CSH 110 2 Capaci tors 80 Cast lebar CBR 110 1 Capac i tor 30 Cast lebar CBR 110 1 Stat ic Var Compensator 60 10 C a thal e e n's Fa l l CF 110 1 Capac i tor 15 Da l ton DLT 110 1 Capaci tor 15 D o o n D OO 1 1 0 1 C a p ac i t o r 1 5 D u nma nway DM Y 110 1 Capac i tor 15 D u n s t ow n 3 DSN 400 1 Shunt Reactor 80 Gor tawee GWE 110 1 Capaci tor 15 Let terkenny LET 110 1 Capaci tor 15 Let terkenny LET 110 1 Stat ic Var Compensator 30 Moy MOY 110 2 Capaci tors 30 Navan NAV 110 1 Capaci tor (1 Mobi le ) 30 Raf feen RAF 110 1 Capaci tor 60 S l igo SL I 110 1 Capaci tor 15 Thur les THU 110 1 Capaci tor 15 T ra lee TRL 110 1 Capac i tor 30 T r ien TRI 110 1 Capaci tor 3 0

2 Tr a n s f o r m e r l i m i t e d t o 2 3 8 M V A a t 1 1 0 k V b y t h e 1 1 0 k V s w i t c h g e a r .

3 T h i s s h u n t r e a c t o r i s o n t h e M o n e y p o i n t - D u n s t o w n 4 0 0 k V l i n e , a t t h e D u n s t o w n e n d .


B-13

Tab le B- 1 0 Ch ar ac ter i s t i cs o f Ex i st ing React ive Compensat ion (cont inued)

M v ar Ca p a bi l i t y Stat ion B u s P la nt

G e nera t e Absorb

W e xford WEX 110 2 Capaci tors 30 Woodland 4 WOO 400 1 Shunt Reactor 80 Tota l 66 5 270

4 T h i s s h u n t r e a c t o r i s o n t h e O l d s t r e e t - W o o d l a n d 4 0 0 k V l i n e a t t h e W o o d l a n d e n d .


B-14

B.2 CHANGES IN NETWORK CHARACTERISTICS

F u t u r e d ev e l o p m e n t s o n t h e n e t wo r k a r e l is t e d i n t h i s s e ct i o n a c c or di n g to t he y e ar in w hi ch

they ar e ex pected to be completed. Th e network changes re lated to each development pro ject

a re grouped together and col lect ively headed by a Capi ta l Project (CP) number and t i t le .

Th e ph ysi c al a nd e lec tr i c al c ha r ac ter i st i c s o f fu t ur e t ra nsmi s si on pl ant or ch a nges t o th e

char acter ist ics brought about by p lanned developments are l is t ed in the tables. These

char acter ist ics ar e indicat ive a t th is s tag e and wi l l be rev iewed when the i tem of p lant is

commiss ioned.

Table B-11 Ch anges in Ci rcui t Char acter is t ics Ex pected Af ter Ju ly 01 s t 2009

Impedance p.u. on 100 MVA

Rating (MVA) Change

Volt (kV)

From To No. Length (km)

R X B Summer W i n te r CP102 Killoteran-Waterford 110 kV Line Diversion Amend 110 KTN WAT 1 5.0 0.004 0.008 0.050 140 140 CP530 Connection of Whitegate Generator into the new Glanagow 220 kV Station Add 220 AD GGO 1 3.8 0.000 0.002 0.104 593 593 CP590 Raffeen-Trabeg No. 2 110 kV Line Uprate Amend 110 RAF TBG 2 9.2 0.006 0.030 0.007 187 223 CP376 Connection of Singland 110 kV Station Add 110 AA SNG 1 5.6 0.004 0.018 0.003 187 223 Add 110 SNG KLN 1 4.1 0.003 0.013 0.003 187 223 Delete 110 AA KLN 1 … … … … … … CP451b Dungarvan-Knockraha 110 kV Line Uprate Amend 110 DGN KRA 1 53.7 0.034 0.175 0.019 187 223

CP563 Connection of Garvagh Wind Farm into Corderry 110 kV Station Add 110 CDY GAR 1 7.3 0.005 0.024 0.003 187 223

CP568 Poolbeg-Shellybanks 220 kV Circuit Uprate Amend 220 PB SHL 1 0.12 0.0001 0.0001 0.003 593 593

CP588 Kilbarry-Mallow 110 kV Line Uprate Amend 110 KBY MAL 1 29.1 0.030 0.097 0.010 137 164

CP600 Connection of Boggeragh Wind Farm into Clashavoon 220 kV Station Add 110 BGH CLA 1 13.5 0.009 0.044 0.005 187 223

CP620 Arva - Gortawee 110kV Line Uprate Amend 110 ARV GWE 1 30.6 0.019 0.099 0.011 187 223


B-15

Table B-11 Ch anges in Ci rcui t Char acter is t ics Ex pected Af ter Ju ly 01 s t 2009 (cont inued)


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP285 Looping of the Tee-Connected Kilteel 110 kV Station Add 110 KTL MAY 1 21.4 0.022 0.071 0.007 120 128 Add 110 KTL MON 1 8.9 0.009 0.030 0.003 120 128 Delete 110 KTL KTL T 1 … … … … … … Delete 110 KLT T MAY 1 … … … … … … Delete 110 KLT T MON 1 … … … … … … CP575 Corraclassey-Gortawee 110kV Line Uprate Amend 110 COR GWE 1 10.9 0.007 0.036 0.004 187 223 CP217 Newbridge Loop-in of the Blake-Cushaling-Maynooth 110 kV Line Add 110 BLK T NEW 1 12.2 0.013 0.041 0.004 137 164

Add 110 CUS NEW 1 31.2 0.033 0.104 0.011 137 164

Delete 110 BLK T CUS 1 … … … … … … CP370 Crane - Wexford 110kV Line Uprate Amend 110 CRA WEX 1 21.3 0.022 0.071 0.007 137 164 CP385 Drybridge - Louth 110kV Line Uprate Amend 110 DRY LOU 1 31.9 0.020 0.104 0.011 187 223 CP454 Ardnacrusha - Limerick 110kV Line Uprate Amend 110 AA LIM 1 11.7 0.007 0.037 0.021 187 223 Connection of Adamstown 110 kV Station Add 110 INC ADM 1 10.5 0.008 0.016 0.105 140 140 Add 110 ADM GCA 1 2.5 0.002 0.004 0.025 140 140 CP601 Connection of Dromada Wind Farm into Trien 110 kV Station (via Athea) Add 110 TRI ATE 1 11.0 0.007 0.036 0.004 187 223

Add 110 ATE DRO 1 7.0 0.005 0.011 0.070 140 140


B-16

Tab le B- 12 Chan ges i n Ci r cui t Char acter is t ics Ex pected in 2010


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r Connection of Kilmahud 110 kV Station Add 110 GCA KUD 1 2.1 0.002 0.003 0.021 140 140 Add 110 GCA KUD 2 2.1 0.002 0.003 0.021 140 140 CP602 Connection of Keelderry Wind Farm into Derrybrien 110 kV Station Add 110 KEE DYN 1 6.5 0.004 0.021 0.002 187 223 CP479 Connection of Athea Wind Farm into Trien 110 kV Station Add 110 ATE TRI 1 11.0 0.007 0.036 0.004 187 223 CP555 Connection of Castledockrill Wind Farm into the new Lodgewood 220 kV Station Add 110 LWD CDK 1 6.6 0.003 0.009 0.041 116 116 Connection of Stevenstown 110 kV station and Loop-in of Finglas-Glasmore 110 kV Line Add 110 GLA SVN 1 18.0 0.017 0.055 0.052 137 154

Add 110 FIN SVN 1 32.2 0.039 0.104 0.056 107 120

Delete 110 FIN GLA 2 … … …. … … … CP592 Construction of Aghada-Rafeen 220 kV Circuit Add 220 AD RAF 1 15.0 0.001 0.010 0.215 431 518 CP489 Connection of Carrowbeg 110 kV Station Add 110 CBR CBG 1 20.0 0.031 0.069 0.006 107 126 CP549 Shannonbridge-Dallow T-Portlaoise 110kV Line Uprate Amend 110 SH DAL T 1 12.0 0.008 0.039 0.007 187 223 Amend 110 DAL T PLS 1 54.7 0.034 0.178 0.019 187 223 CP584 Shannonbridge-Ikerrin T 110 kV Line Uprate Amend 110 SH IKE T 1 53.7 0.034 0.175 0.019 187 223 CP254 Cashla Loop-in of Dalton-Galway 110 kV Line Add 110 CSH DLT 1 52 0.081 0.179 0.017 107 126 Add 110 CSH GAL 4 18.5 0.029 0.064 0.006 107 126 Delete 110 DLT GAL 1 … … … … … … CP041 Connection of Hartnett's Cross 110 kV Station Add 110 HTS MAC 1 4.5 0.007 0.016 0.002 107 126 CP197 Construction of Cushaling-Thornsberry 110 kV Line Add 110 CUS TSB 1 32.0 0.0201 0.104 0.0113 187 223 CP138 Connection of Nenagh 110 kV Station Add 110 KLN NEN 1 33.6 0.052 0.116 0.011 107 126


B-17

T a b l e B - 1 2 C h a n ges i n Ci r c ui t C h ar a ct e r i s t i cs Ex pec t e d i n 2 0 10 ( c o nt i n u e d)


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP173 Connection of Banoge 110 kV Station Add 110 ARK BOG 1 22.6 0.035 0.078 0.007 107 126 Add 110 BOG CRA 1 26.9 0.042 0.093 0.009 107 126 Delete 110 ARK CRA 1 … … … … … … CP175 Charleville-Killonan 110 kV Line Uprate Amend 110 CHA KLN 1 36.9 0.039 0.123 0.013 137 164 CP201 Loop-in of Athy 110 kV Add 110 ATY CLW 1 25.0 0.039 0.086 0.008 107 126 Add 110 ATY PLS 1 26.6 0.041 0.092 0.009 107 126 Delete 110 CLW ATY T 1 … … … … … … Delete 110 PLS ATY T 1 … … … … … … Delete 110 ATY ATY T 1 … … … … … … CP218 Construction of Gorman-Navan 3rd 110 kV Line Add 110 GOR NAV 3 6.5 0.007 0.022 0.002 137 164 CP241 Construction of Lodgewood 220 kV Station Add 220 ARK LWD 1 40.5 0.005 0.035 0.053 431 518 Add 110 CRA LWD 1 8.0 0.005 0.026 0.003 187 223 Add 220 GI LWD 1 48.3 0.006 0.042 0.063 431 518 Add 220/110 LWD LWD 1 … 0.001 0.064 … 250 250 Delete 220 ARK GI 1 … … … … … … CP061 Maynooth-Kilteel-Monread 110 kV Line Uprate Amend 110 KTL MAY 1 21.4 0.022 0.071 0.007 137 164 CP246 Construction of Tralee-Tarbert 2nd 110 kV Line Add 110 TB TRL 2 47.0 0.030 0.153 0.017 187 223 CP626 Killonan - Knockraha 220kV Line Uprate Amend 220 KLN KRA 1 82.4 0.055 0.085 0.000 431 518


B-18

T a b l e B - 13 Ch a n g e s i n Ci r c ui t C h ar a ct e r i s t i cs Ex pec t e d i n 2 0 11


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP228 Kilbarry-Marina 110 kV Line Uprating Amend 110 KBY MR 1 4.0 0.004 0.013 0.003 111 143 Amend 110 KBY MR 2 4.0 0.004 0.013 0.003 111 143 CP544 Connection of Salthill 110 kV Station Add 110 GAL SAL 1 5.8 0.004 0.009 0.059 140 140 Add 110 CSH SAL 1 24.6 0.033 0.073 0.067 107 126 Delete 110 CSH GAL 4 … … … … … … CP641 Construction of Nore 110kV Station and Lines Add 110 KKY NO 1 3.6 0.002 0.004 0.022 140 143 CP292a Construction of Gorman-Meath Hill 110 kV Line Add 110 GOR MTH 1 27 0.028 0.090 0.009 137 164 CP374 Construction of Arva-Shankill 2nd 110 kV Line Add 110 ARV SKL 2 18.0 0.011 0.059 0.006 187 223 CP406 Cashla-Cloon 110 kV Line Uprate Amend 110 CSH CLN 1 22.8 0.014 0.074 0.008 187 223 CP587 Construction of Glanagow-Rafeen 220 kV Circuit Add 220 GGO RAF 1 9.5 0.000 0.004 0.260 593 593 CP615 Construction of Glenree 110 kV Station and Lines Add 110 CUN GLR 1 27.9 0.043 0.096 0.009 107 126 Add 110 MOY GLR 1 14.2 0.022 0.049 0.005 107 126 Delete 110 CUN MOY 1 … … … … … … CP552 Athlone-Shannonbridge 110 kV Line Uprate Amend 110 ATH SH 1 21.6 0.014 0.070 0.016 187 223 CP211 Construction of Srananagh 220 kV Station and Lines Add 220 FLA SRA 1 55 0.006 0.048 0.072 431 518 Add 220/110 SRA SRA 2 … 0.001 0.064 … 250 250 CP644 Construction of Bracklone 110kV Station and Lines Add 110 PLS BRA 1 19.3 0.030 0.067 0.006 107 126 Add 110 NEW BRA 1 22.96 0.024 0.077 0.008 107 126 Delete 110 NEW PLS 1 … … … … … …


B-19

Tab le B- 1 4 Ch an ges i n Ci r cui t Char acter is t ics Ex pected in 2012


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r Connection of Cauteen 110 kV Station Add 110 KLN CTN 1 28.1 0.044 0.098 0.009 107 126 Add 110 TIP CTN 1 13.2 0.021 0.046 0.004 107 126 Delete 110 KLN TIP 1 … … … … … … Connection of Ballakelly Generator into the new Ballakelly 220 kV Station Add 220 BY LOU 1 1.5 0.000 0.001 0.041 593 593 CP261 Construction of Athlone-Shannonbridge 2nd 110 kV Line Add 110 ATH SH 2 25.0 0.016 0.081 0.009 187 223 Connection of Cherrywood 110 kV Station Add 110 CKM CHE 1 4 0.004 0.008 0.030 107 126 Add 110 CHE CHE T 1 2.2 0.004 0.008 0.001 107 126 Add 110 FAS CHE T 1 5.0 0.008 0.017 0.002 107 126 Add 110 CKM CHE T 1 2.9 0.005 0.010 0.001 107 126 Delete 110 CKM FAS 1 … … … … … … CP125 Connection of Screeb 110 kV Station Add 110 SCR SAL 1 53.2 0.053 0.166 0.048 120 131 CP466 Construction of a new 400 kV Mid-Cavan Station Add 400/220 MCV MCV 1 … 0.000 0.027 … 500.0 500.0 Add 400.0 MCV TLE 1 82.0 0.002 0.018 0.414 1424.0 1713.0 Add 400.0 MCV WOO 1 58.0 0.001 0.013 0.293 1424.0 1713.0 Add 220.0 FLA MCV 1 90.0 0.011 0.078 0.118 431.0 518.0 Add 220.0 LOU MCV 1 20.0 0.002 0.017 0.026 431.0 518.0 Delete 220.0 FLA LOU 1 110.1 0.013 0.095 0.144 431.0 518.0


B-20

Tab le B- 15 Chan ges i n Ci r c ui t Char acter is t ics Ex pected in 2013


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP075 Construction of Ballycummin 110 kV station Add 110 BCM MTN 1 4.6 0.003 0.015 0.002 187 223 Add 110 LIM BCM 1 3.7 0.003 0.012 0.001 137 164 Delete 110 LIM MTN 1 … … … … … … CP506 Construction of Finnstown 220 kV Station Add 220 INC FNT 1 10.6 0.001 0.009 0.014 431 518 Add 220 INC FNT 2 10.6 0.001 0.009 0.014 431 518 Add 220 MAY FNT 1 9.7 0.001 0.009 0.013 431 518 Add 220 MAY FNT 2 9.7 0.001 0.009 0.013 431 518 Delete 220 INC MAY 1 … … … … … … Delete 220 INC MAY 2 … … … … … … Add 220/110 FNT FNT 1 … 0.001 0.065 … 250 250 Add 110 INC GCA 3 8.0 0.006 0.012 0.080 140 140 Add 110 FNT GCA 1 0.9 0.001 0.001 0.009 140 140 Add 110 FNT GCA 2 0.9 0.001 0.001 0.009 140 140 Add 110 FNT ADM 1 1.6 0.001 0.002 0.016 140 140 Add 110 FNT ADM 2 1.6 0.001 0.002 0.016 140 140 Delete 110 INC ADM 1 … … … … … … Delete 110 ADM GCA 1 … … … … … … CP437 Connection of Balgriffin 220 kV Station Add 220 BGF FIN 1 17.0 0.001 0.007 0.465 593 593 Add 220/110 BGR BGR 1 … 0.001 0.065 … 250 250 CP501 Construction of Clashavoon-Dunmanway 110 kV Line Add 110 CLA DMY 1 35.0 0.022 0.114 0.012 187 223


B-21

T a b l e B - 1 5 C h a n ges i n Ci r c ui t C h ar a ct e r i s t i cs Ex pec t e d i n 2 0 13 (c o n t i n u e d)


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP647 Construction of a new Kilpaddoge 220/110 kV Station Add 220 KPG TB 1 3.3 0.000 0.003 0.004 431 518 Add 220 KPG TB 2 3.3 0.000 0.003 0.004 431 518 Add 220 KPG KLN 1 68.0 0.008 0.059 0.089 431 518 Add 220 KPG CLA 1 94.7 0.011 0.082 0.124 431 518 Add 110 KPG AUG 1 32.8 0.021 0.107 0.012 187 223 Add 110 KPG RAT 1 32.2 0.033 0.108 0.011 137 164 Add 110 KPG TRI 1 19.4 0.020 0.065 0.007 120 128 Add 110 KPG TRL 1 39.4 0.060 0.135 0.013 107 126 Add 110 KPG TRL 2 44.4 0.046 0.148 0.015 137 164 Delete 220 TB KLN 1 … … … … … … Delete 220 TB CLA 1 … … … … … … Delete 110 TB AUG 1 … … … … … … Delete 110 TB RAT 1 … … … … … … Delete 110 TB TRI 1 … … … … … … Delete 110 TB TRL 1 … … … … … … Delete 110 TB TRL 2 … … … … … … Construction of Kilpaddoge - Moneypoint 220 kV cable Add 220 KPG MP 1 5.5 0.000 0.002 0.150 593 593 Construction of new Ralapanne 110 kV station Add 110 RAL KPG 1 3.4 0.002 0.011 0.001 187 223 Add 110 RAL KPG 2 3.4 0.002 0.011 0.001 187 223 CP603 Construction of Mulreavy 110 kV Station Add 110 MRY CF 1 31.3 0.020 0.102 0.011 187 223 CP421b Construction of Bunbeg 110 kV Station Add 110 BUN TIV 1 35.0 0.054 0.120 0.011 107 126 CP421 Construction of Binbane-Letterkenny 110 kV Line Add 110 BIN TIV 1 22.0 0.014 0.072 0.008 187 223 Add 110 LET TIV 1 47.0 0.030 0.153 0.017 187 223 CP596 Construction of Mullingar - Kinnegad 110kV line Add 110 MUL KIN 1 27.0 0.017 0.088 0.010 187 223


B-22

Table B-16 Ch anges in Ci rcui t Char acter is t ics Ex pected Beyond 2013


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP 500 Construction of Knockanure 220/110 kV Station Add 220 KNR CLA 1 77.3 0.009 0.067 0.101 431 518 Add 220 KNR KPG 1 17.3 0.002 0.015 0.023 431 518 Delete 220 KPG CLA 1 … … … … … … Add 110 ATE KNR 1 9.5 0.006 0.031 0.003 187 223 Add 110 KNR TRI 1 4.4 0.005 0.017 0.002 120 128 Add 110 KNR TRI 2 5.7 0.004 0.019 0.002 187 223 Add 110 KNR KPG 1 15.0 0.015 0.050 0.005 137 164 Delete 110 ATE TRI 1 … … … … … … Delete 110 KPG TRI 1 … … … … … … CP608 Construction of Knocknagashel 110 kV Station Add 110 KNG TRI 1 13.1 0.008 0.043 0.005 187 223 CP650 & CP651 Construction of Ballyvouskill and Kishkeam 220/110 kV Stations Add 220 BVK CLA 1 18.4 0.002 0.016 0.024 431 518 Add 220 KKM BVK 1 14.5 0.002 0.013 0.019 431 518 Add 220 KKM KNR 1 47.0 0.006 0.041 0.062 431 518 Delete 220 KNR CLA 1 … … … … … … Add 110 BVK GRO 1 4.0 0.003 0.013 0.002 187 223 Add 110 BVK GRO 2 4.0 0.003 0.013 0.002 187 223 Add 110 KKM GLE 1 12.5 0.008 0.041 0.004 187 223 Construction of Cordal 110 kV Station Add 110 KKM CDL 1 8.2 0.005 0.027 0.003 187 223 CP606 Construction of Knockacummer 110 kV Station Add 110 GLE KCR 1 11.2 0.008 0.017 0.112 140 140 CP585 Construction of a new Laois 400 kV Add 380 DSN LSE 1 44.8 0.001 0.010 0.226 1424 1713 Add 380 MP LSE 1 170.0 0.003 0.038 0.858 1424 1713 Add 400/110 LSE LSE 1 … 0.001 0.027 … 250 250 Add 400/110 LSE LSE 2 … 0.001 0.027 … 250 250 Add 110 PLS LSE 1 9.7 0.015 0.033 0.003 107 126 Add 110 ATY LSE 1 21.9 0.034 0.076 0.007 107 126 Delete 400 DSN MP 1 … … … … … … Delete 110 ATY PLS 1 … … … … … … Connection of Ballyragget 110 kV Station Add 110 LSE BGT 1 28.0 0.018 0.091 0.010 187 223 Add 110 KKY BGT 1 22.0 0.014 0.071 0.008 187 223 CP597 Construction of Killonan - Ardnacrusha 110 kV Line Add 110 AA KLN 1 10.6 0.007 0.035 0.004 187 223


B-23

Table B-16 Ch anges in Ci rcui t Char acter is t ics Ex pected Beyond 2013 (c ont inued)


Rating (MVA) Change

Volt (kV)


R X B Summer W i n te r CP597 Moneypoint - Tullabrack T - Booltiagh Line Uprate Amend 110 MP TBK T 1 6.6 0.004 0.022 0.002 187 223 Amend 110 TBK T BOL 1 19.6 0.012 0.064 0.007 187 223 CP597 Booltiagh - Ennis Line Uprate Amend 110 BOL ENN 1 24.0 0.015 0.078 0.009 187 223 Construction of Muingnaminnane 110 kV Station Add 110 TRL MUI 1 14.0 0.010 0.021 0.141 140 140 CP250 Construction of Castlebar - Tonroe 220 kV Line Add 110 CBR TON 1 53.2 0.024 0.185 0.089 187 223

Tabl e B-17 Ch aracter is t ics o f Gr id Tr ansformers Ex pect ed in 2009

Impedance p.u. on 100

MVA

Voltage Ratio Tapping

Range Station / Transformer Rating

(MVA) HV/LV (kV)

R X + -

CP264 Finglas T2105 250 220/110 0.001 0.064 9% 17%

Tabl e B-18 Character is t ics o f Gr id Tr ansformers Ex pect ed in 2010


MVA



(MVA) HV/LV (kV)

R X + -

CP 511 Killonan T2103 250 220/110 0.000 0.063 9% 18%

CP 586 Knockraha T2103 250 220/110 0.001 0.065 9% 17%

CP 241 Lodgewood T2101 250 220/110 0.001 0.064 10% 18%

CP600 Clashavoon T2102 250 220/110 0.000 0.065 9% 17%

CP 513 Carrickmines T2103 250 220/110 0.001 0.064 9% 17%

CP 523 Inchicore T2103 250 220/110 0.000 0.060 9% 18%


B-24



MVA



(MVA) HV/LV (kV)

R X + -

CP211 Srananagh T2101 250 220/110 0.001 0.064 9% 18%



MVA



(MVA) HV/LV (kV)

R X + -

CP466 Mid-Cavan T4201 500 400/220 0.000 0.027 10% 7%

CP 483 Carrickmines T2104 250 220/110 0.001 0.065 9% 17%

Tabl e B-21 Character is t ics o f Gr id Tr ansformers Ex pect ed in 2013


MVA



(MVA) HV/LV (kV)

R X + -

CP 43 7 Balgriffin T2101 250 220/110 0.001 0.064 9% 17%

CP 506 Finnstown T2101 250 220/110 0.001 0.064 9% 17%

CP 647 Kilpaddoge T2101 250 220/110 0.001 0.065 9% 17% Kilpaddoge T2102 250 220/110 0.001 0.065 9% 17% Kilpaddoge T2103 250 220/110 0.001 0.065 9% 17%

C P39 9 Moneypoint T4201 500 400/220 0.000 0.027 10% 7%

CP 500 Knockanure T2101 250 220/110 0.001 0.064 9% 17%

CP 650 Ballyvouskill T2101 250 220/110 0.001 0.064 9% 17%

CP651 Kishkeam T2101 250 220/110 0.001 0.064 9% 17%


B-25

Tabl e B-22 Ch aracter is t ics o f Gr id Tr ansformers Ex pect ed Beyond 2013


MVA



(MVA) HV/LV (kV)

R X + -

CP 585 Laois T4101 250 400/110 0.000 0.072 15% 15% Laois T4102 250 400/110 0.000 0.072 15% 15%

CP 597 Moneypoint T2101 250 220/110 0.001 0.065 9% 17%

Tabl e B-23 Ch aracter is t ics o f Reac t ive Compensat ion Expect ed in 2010

Mvar Capability Station Bus Plant

Generate Absorb

CP 512 Ki lkenny KKY 110 2 Capaci tors (2 x 15 ) 30 -

CP 594 Mul l ingar MUL 110 2 Capaci tors (2 x 15 ) 30 -

CP 514 A rdnacru sh a AA 110 1 Capac i tor 30 -

CP 528 K i l te el KTL 110 1 Capac i tor 30 -

CP 467 Lou th LOU 110 1 Capac i tor 30 -

CP618 L isdrum L IS 110 2 Capaci tors (2 x 15 ) 30 -

CP 515 Druml ine DRU 110 1 Capaci tor 15 -

CP 529 Thur les THU 110 1 Capaci tor 15 -

Ta ble B-24 Ch aracter is t ics o f Reac t iv e Compensat ion Expect ed in 2016

Mvar Capability Station Bus Plant

Generate Absorb

CP619 Shanki l l SKL 110 1 Capaci tor 30 - Shanki l l SKL 110 1 Capaci tor 15 -

demand forecasts at indiVidual transmission interface stations

APPENDIX C


C-1

APPENDIX C DEMAND FORECASTS AT INDIVIDUAL TRANSMISSION INTERFACE

STATIONS

Transmiss ion in ter face s tat ions ar e the poi nt s o f c o n n e ct i o n b e tw e e n t h e t r a ns mi s si o n

system and the di st r ibut ion system or d i rect ly -connected customers . Tables C-1 to C-3 l is t

the demand forecasts a t each inter face s tat ion f o r e a ch o f t h e s ev e n yea r s t o 2 0 1 6 a t t h e

t ime of system wi nter peak, summer peak and summer val ley , respect ively .

The s tat ion demand va lues do not inc l ude t rans m i s si o n l os s e s . D e m an d a t s t at i on s t h a t

i n t er f ac e w i th t h e di s t r i but i o n s y st e m d o i n c l u d e d i s t r i b ut i o n l o s s es .

A l l t ransmiss ion inter face s tat ions ar e 110 kV s tat ions except for the four 220 kV in ter fac e

s ta t ions that sup ply the Dubl i n C i ty n etworks operated by the DSO. Th ese 220 kV in ter fac e

s tat ions, Car r ickmines, F ing las , Inch icore and Pool beg, are inc luded at the bot tom of the

table .

S o m e 1 1 0 kV s t at i o n s d o n o t i nt er f a ce wi th d is t r ibut ion s tat ions or d i rect l y -connected

demand stat ions. As there are no demand va lues for such s tat ions, they are not inc l uded in

t h i s t a bl e .

Tabl e C-1 Demand Forecasts at T ime of Winter P eak

Demand Forecast (M W) B u s

Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

AA ARDNACRU 0.96 76.4 78.0 79.8 81.5 83.3 85.1 86.9

A D A GHADA 0. 97 1.8 1.9 1.9 2.0 2.0 2.0 2.1

A HA A HANE 0. 99 5.5 5.6 5.8 5.9 6.0 6.1 6.3

ANR ANNER 0.94 11.0 11.0 11.0 11.0 11.0 11.0 11.0

ARI ARIGNA 1 .00 3.7 3.8 3.8 3.9 4.0 4.1 4.2

ARK ARKLOW 0.99 33.8 34.5 35.3 36.1 36.9 37.6 38.4

ATH ATHLONE 0.95 59.7 61.0 62.4 63.7 65.1 66.5 67.9

ATY ATHY 0.95 16.7 17.1 17.5 17.9 18.2 18.6 19.0

BAL BALTRASN 0.97 25.8 26.2 26.7 27.1 27.6 28.0 28.5

BAN BANDON 0.96 29.9 30.6 40.5 41.4 42.3 43.2 44.1

BAR BARRYMOR 0.96 23.6 24.1 24.6 25.1 25.7 26.2 26.8

B CM B A L L Y CU M 0 . 9 6 - - - 9.5 9.8 10.0 10.2

B D A B A R OD A 0 . 9 6 19.0 19.0 19.0 19.0 19.0 19.0 19.0

BDN BALLYDIN 0 .96 17.8 18.1 18.3 18.6 18.9 19.2 19.4

B EG B A L L YB EG 0 . 9 5 13.2 13.5 13.8 14.1 14.4 14.7 15.0

B IN B INBANE 0.95 22.2 22.7 23.2 14.2 14.5 14.8 15.1

BK BELLACO R 0.96 6.1 6.3 6.4 6.5 6.7 6.8 7.0

BL I BALLYL IC 0 .99 12.7 13.0 13.3 13.6 13.9 14.2 14.5

B L K B L A K E 0 . 9 7 30.6 19.4 19.8 20.2 20.7 21.1 21.6

B OG B A N OG E 0 . 9 5 14.1 14.4 14.7 15.0 15.3 15.6 16.0


C-2

Table C-1 Demand Forecasts a t T i m e of Wi n t er P eak ( c o nt i n u e d)


Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

BRI BRINNY 0.95 4.2 4.2 4.2 4.2 4.2 4.2 4.2

BRY BARNAHEL 0 .98 28.3 28.9 29.6 30.2 30.8 31.5 32.2

B U N B U NB EG 0 . 9 5 - - - 14.2 14.5 14.8 15.1

BUT BUTLERST 0 .98 37.4 38.2 39.0 39.9 40.7 41.6 42.5

CAH CAHIR 0 .97 23.0 23.4 23.9 24.3 24.8 25.3 25.7

CB G CARROWBE 0.96 19.7 20.1 20.6 21.0 21.5 21.9 22.4

CB R CASTLEB A 0.93 34.4 35.2 36.0 36.7 37.5 38.3 39.1

CF CATH_FAL 0 .95 17.0 17.4 17.8 18.2 18.6 18.9 19.4

CFM CASTLEFA 0.95 44.0 44.0 44.0 44.0 44.0 44.0 44.0

CHA CHARLEVI 0 .94 21.3 21.7 22.2 22.7 23.2 23.7 24.2

CLN CLOON 0.95 25.7 26.3 26.9 27.5 28.1 28.6 29.3

CLW CARLOW 0.97 53.9 66.9 81.5 83.3 85.1 86.9 88.8

COL COLLEGE 0.95 38.3 38.7 39.0 39.4 39.7 40.1 40.5

COS CARICKON 0.98 28.2 28.8 29.4 30.1 30.7 31.4 32.0

C O W C O W 0 . 9 9 17.2 17.6 18.0 18.4 18.8 19.2 19.6

CRA CRANE 0.97 31.9 32.6 33.3 34.0 34.8 35.5 36.3

CRO COOLROE 1 .00 10.4 10.6 10.8 11.1 11.3 11.5 11.8

CVW CASTLEVI 0 .98 22.4 22.8 23.4 23.9 24.4 24.9 25.4

DAL DALLOW 0.97 16.0 16.4 16.8 17.1 17.5 17.9 18.2

D D K D U ND A L K 0 . 9 7 42.4 43.3 44.2 45.2 46.2 47.2 48.2

DFR DUNFIRTH 0.98 6.0 6.1 6.3 6.4 6.5 6.7 6.8

D G N D U NG A R V A 0 . 9 8 30.6 31.2 31.9 32.6 33.3 34.0 34.7

DLT DALTON 0.95 20.4 20.8 21.3 21.7 22.2 22.7 23.2

D M Y D U NM A N W A 0 . 9 6 32.2 32.9 29.4 30.0 30.7 31.3 32.0

D OO D OO N 0 . 9 8 30.4 31.1 31.8 32.5 33.2 33.9 34.6

D R U D R UM LINE 0 . 92 25.4 26.0 33.5 34.1 34.7 35.3 35.9

DRY DRYBRIDG 0.97 82.6 84.4 86.3 88.1 90.0 91.9 93.9

ENN ENNIS 0.96 70.0 71.1 72.2 73.4 74.5 75.7 76.9

G A L G A L WA Y 0 . 9 7 143.0 90.5 92.5 94.5 96.5 98.6 100.7

G CA G RA NG E 0 . 9 5 59.2 60.3 61.6 62.8 64.0 65.2 66.5

G I G RE A T 0 . 9 5 21.8 22.3 22.8 23.3 23.8 24.3 24.8

G I L G I L RA 0 . 9 5 11.9 11.9 11.9 11.9 11.9 11.9 11.9

G L A G L A SM O RE 0 . 9 4 53.6 54.8 56.0 57.2 58.5 59.7 61.0

GLE GLENLARA 0.91 11.6 11.9 12.1 12.4 12.7 12.9 13.2

G RA G RA NG E 0 . 9 5 53.8 55.0 56.2 57.4 58.7 59.9 61.2

G RI G RI F F I NR 0 . 9 7 59.6 60.8 62.2 63.5 64.9 66.3 67.7

G W E G O R T AW E E 0 . 9 5 26.0 26.1 26.3 26.5 26.8 27.0 27.2

HTS HARNETTS 0.99 8.0 8.1 8.3 8.5 8.7 8.9 9.1

IKE IKERRIN 0.96 26.1 26.7 27.3 27.9 28.5 29.1 29.7

KBY K ILBARRY 0.98 89.2 91.1 93.2 95.2 97.2 99.3 101.4

KER KNOCKERA 0.96 30.4 31.0 31.7 32.4 33.1 33.8 34.5

K I N K I N N E G AD 0 . 9 5 11.7 11.7 11.7 11.7 11.7 11.7 11.7


C-3



Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

KKY K ILKENNY 0.96 63.1 64.4 65.9 67.3 68.7 70.2 71.7

K L M K I L M O RE 0 . 9 5 32.7 32.9 33.2 33.4 33.6 33.9 34.1

KTL K ILTEEL 0 .93 31.9 32.5 33.3 34.0 34.7 35.5 36.2

KTN K ILLOTER 0.95 9.8 10.0 10.2 10.5 10.7 10.9 11.1

K U D K I L M AH U D 0 . 9 5 23.8 23.8 23.8 23.8 23.8 23.8 23.8

KUR KNOCKUMB 0.95 24.2 24.2 24.2 24.2 24.2 24.2 24.2

LA LANESBOR 0.96 15.6 15.9 16.3 16.7 17.0 17.4 17.7

LET LETTERKE 0.95 62.8 64.1 65.6 62.3 63.7 65.1 66.4

L IB L IBERTY 0 .89 18.6 19.0 19.4 19.9 20.3 20.7 21.2

L IM L IMERICK 0.98 72.2 73.7 75.4 67.4 68.9 70.4 71.9

L IS L ISDRUM 0.97 25.7 26.2 26.8 27.4 28.0 28.6 29.2

MAC MACROOM 0.98 9.1 9.3 4.5 4.6 4.7 4.8 4.9

MAL MALLOW 0.97 20.7 21.1 21.6 22.1 22.6 23.0 23.5

MCE MACETOWN 0.97 29.6 30.1 30.6 31.2 31.8 32.3 32.9

M I D M I D L E TO N 0 . 9 7 36.6 37.4 38.2 39.0 39.9 40.7 41.6

MLN MULLAGHA 0.96 28.0 28.4 28.9 29.3 29.8 30.3 30.7

M O N M O N R E AD 0 . 9 8 15.6 15.9 16.3 16.7 17.0 17.4 17.7

M O Y M O Y 0 . 9 7 30.6 31.3 32.0 32.6 33.4 34.1 34.8

MR MARINA 0.98 20.2 20.6 21.1 21.6 22.0 22.5 23.0

M T H M E A T H 0 . 9 5 39.6 40.5 41.4 42.3 43.2 44.1 45.0

M U L M U L LI N G A 0 . 9 7 46.6 47.6 48.7 49.7 50.8 51.9 53.0

MUN MUNG RET 0 .95 25.7 25.7 25.7 25.7 25.7 25.7 25.7

NAN NANG OR 0.95 26.0 26.0 26.0 26.0 26.0 26.0 26.0

NAV NAVAN 0.96 68.3 69.7 71.3 72.8 74.4 76.0 77.6

NEN NENAGH 0.95 25.5 26.0 26.6 27.2 27.8 28.4 29.0

NEW NEWBRIDG 0.98 45.9 46.9 48.0 49.0 50.1 51.1 52.2

O L D O L D C OU R T 0 . 9 4 0.3 0.3 0.3 0.3 0.3 0.3 0.3

O UG O UG H T R A G 0 . 9 8 25.8 26.3 26.9 27.5 28.1 28.7 29.3

PLA PLATIN 0 .95 54.6 54.6 54.6 54.6 54.6 54.6 54.6

P L S P O RTL AO I 0 . 9 5 39.9 40.7 41.7 42.6 43.5 44.4 45.4

RAT RATHKEAL 0 .96 25.4 26.0 26.6 27.1 27.7 28.3 28.9

R IC R ICHMOND 0.96 32.2 32.9 33.7 34.4 35.1 35.9 36.7

RNW RINAWADE 0.95 15.2 15.2 15.2 15.2 15.2 15.2 15.2

RSY R INGASKI 0 .98 4.9 5.0 5.1 5.2 5.3 5.4 5.6

RYB RYEBROOK 0.95 81.0 81.0 81.0 81.0 81.0 81.0 81.0

SAL SALTHILL 0 .97 - 42.8 43.7 44.7 45.6 46.6 47.6

SKL SHANKILL 0 .94 47.5 48.5 49.6 50.7 51.8 52.9 54.0

SL I SL IGO 0.96 53.1 54.2 55.4 56.6 57.8 59.1 60.3

S N G S I N G L A ND 0 . 9 6 10.7 11.0 11.2 11.5 11.7 12.0 12.2

SOM SOMERSET 0 .98 24.2 24.7 25.2 25.8 26.3 26.9 27.5

STR STRATFOR 0.97 22.9 23.4 23.9 24.4 24.9 25.5 26.0

SVN STEVENST 0.95 11.6 11.9 12.2 12.4 12.7 13.0 13.2

TBG TRABEG 0.98 65.3 66.7 68.2 69.7 71.2 72.7 74.3


C-4



Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

TBK TULLABRA 0.91 11 .2 11 .4 11 .7 11 .9 12 .2 12 .4 12 .7

THU THURLES 0.94 28.2 28.8 29.5 30.1 30.7 31 .4 32.1

T IP T IPPERAR 0.97 15 .7 16.1 16.4 16.8 17 .1 17 .5 17 .9

TLK TRILL ICK 0.99 16.8 17 .2 17 .6 17 .9 18.3 18.7 19 .1

TON TONROE 0.95 12.6 12.9 13 .2 13 .5 13 .7 14 .0 14.3

TRI TR IEN 0.95 23 .1 23 .6 24 .1 24.6 25.2 25.7 26.3

TRL TRALEE 0 .92 44.7 45.6 46.7 47 .7 48.7 49.7 50.8

T S B T H O R N SB E 0 . 9 7 3 1 . 7 3 2 . 4 3 3 . 1 3 3 . 8 3 4 . 5 3 5 . 3 3 6 . 0

WAT WATERFOR 0.99 41 .9 42.8 43.7 44.7 45.6 46.6 47.6

WEX WEXFORD 0.97 53.9 55 .0 56.3 57 .5 58.7 60.0 61 .2

WHI WHITEG AT 0 .95 7 .0 7 .0 7 .0 7 .0 7 .0 7 .0 7 .0

CKM C a r r i c k mi n es 0 . 9 6 3 0 7 .4 3 13 . 9 340.1 346.9 354.0 361 .2 368.5

F I N F i n g l as 0 . 9 5 3 1 1 . 5 3 1 7 . 8 3 24.6 331 .2 338.0 344.9 351 .9

I N C Inchicor e 0 .95 224.2 228.8 23 3.8 23 8.6 243 .5 248.5 253 .6

P B Pool beg 0 . 97 184.0 187.7 191 .6 195.4 199.4 203.3 207.4

T O T A L 4 5 1 9 4 5 9 2 4 7 2 3 4 8 1 3 4 9 0 5 4 9 9 9 5 0 9 4

Tabl e C-2 Demand Forecasts a t T ime of Summer P eak


Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

AA ARDNACRU 0.96 77 .2 57 .3 58.8 59.8 61 .1 62.5 63.9

AD AGHADA 1 .00 1 .2 1 .2 1 .2 1 .2 1 .3 1 .3 1 .3

A H A A H A N E 0 . 9 8 4 . 1 4 . 1 4 . 3 4 . 3 4 . 4 4 . 5 4 . 6

ANR ANNER 0.94 11 .0 11 .0 11 .0 11 .0 11 .0 11 .0 11 .0

ARI ARIGNA 0.97 4 .3 4 .4 4 .5 4 .6 4 .7 4 .8 4 .9

ARK ARKLOW 0.96 37 .2 31 .4 3 2.3 3 2. 8 33 . 5 3 4 . 2 3 5. 0

ATH ATHLONE 0.95 52.5 53.6 55 .1 56.0 57 .3 58.5 59.8

ATY ATHY 0.95 8.2 14.2 14.6 14.8 15 .2 15 .5 15 .8

BAL BALTRASN 0.97 21 .6 21 .9 22.3 22.6 23.0 23.4 23.7

BAN BANDON 0.92 23.8 24.3 25 .0 33.2 34.0 34.7 35 .5

BAR BARRYMOR 0.97 17 .8 18.2 18.7 19 .0 19.4 19.9 20.3

BCM BALLYCU M 0.96 - - - 7 .9 8 .1 8 .3 8 .5

BDA BARODA 0.96 19.0 19.0 19.0 19.0 19.0 19.0 19.0

BDN BALLYDIN 0.95 15 .5 15 .7 16.0 16.1 16.4 16.6 16.8

BEG BALLYBEG 0. 97 8 .6 8 .8 9 .1 9 .2 9 .4 9 .6 9 .8

B IN BINBANE 1 .00 12.9 13 .2 13 .6 13 .8 6 .0 6 .1 6 .3

B K B E L L A CO R 0 . 9 4 3 . 7 3 . 8 3 . 9 4 . 0 4 . 1 4 . 2 4 . 3

BL I BALLYL IC 0 .79 5 .7 5 .8 6 .0 6 .1 6 .2 6 .4 6 .5

BLK BLAKE 0.92 21 .4 21 .9 12 .3 12 .5 12 .8 13 .1 13 .4

BOG BANOGE 0.95 - 11 .9 12 .2 12 .4 12 .7 13 .0 13 .3

BRI BRINNY 0.95 4 .2 4 .2 4 .2 4 .2 4 .2 4 .2 4 .2


C-5

Tabl e C-2 Demand Forecasts at T i me of Summer P eak (cont inued)


Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

BRY BARNAHEL 0 .96 35 .2 36.0 37 .0 37 .6 38.4 39.2 40.1

BUN BUNB EG 0.95 - - - - 12 .0 12.3 12 .6

BUT BUTLERST 0.96 25.3 25.8 26.5 27 .0 27.6 28.2 28.8

CAH CAHIR 0 .94 23.2 23.7 24.3 24.6 25.1 25 .6 26.1

CBG CARROWBE 0.96 - 16 .7 17 .2 17 .4 17 .8 18.2 18.6

CBR CASTLEBA 0.93 42.9 27 .2 27 .9 28.4 29.0 29.7 30.3

CF CATH_FAL 0 .94 14.8 15 .1 15 .6 15 .8 16.2 16.5 16.9

CFM CASTLEFA 0 .95 44.0 44.0 44.0 44.0 44.0 44.0 44.0

CHA CHARLEVI 0 .92 12.3 12 .6 12 .9 13 .1 13 .4 13 .7 14 .0

CLN CLOON 0.94 17 .3 17 .7 18.2 18.5 18.9 19.3 19 .7

CLW CARLOW 0.95 37 .3 42.2 53.5 65.5 66.9 68.4 69.9

COL COLLEGE 0.96 40.3 40.7 41 .2 41 .5 41 .9 42.4 42.8

COS CARICKON 0.94 28.6 29.2 30.0 30.5 31 .2 31 .9 32.6

COW COW 0.98 15 .5 15 .8 16.2 16.5 16.9 17 .2 17 .6

CRA CRANE 0.93 23.2 18.5 19 .0 19.3 19 .7 20.2 20.6

CRO COOLROE 0.98 12.1 12 .4 12 .7 12 .9 13 .2 13 .5 13 .8

CVW CASTLEVI 0 .97 23.3 23.8 24.5 24.9 25.4 26.0 26.6

DAL DALLOW 0.89 8.3 8 .5 8 .7 8 .9 9 .1 9 .3 9 .5

DDK DUND ALK 0.95 29.0 29.7 30.5 31 .0 31 .7 32.4 33.1

D F R D U NFI RTH 0 . 9 6 3 . 7 3 . 8 3 . 9 3 . 9 4 . 0 4 . 1 4 . 2

D G N D U NG A R V A 0 . 9 6 2 3 . 0 2 3 . 5 24.2 24.6 25.1 25.7 26.2

DLT DALTON 0.96 9 .9 10.2 10.4 10.6 10.8 11 .1 11 .3

DMY DUNM ANWA 0.92 26.6 27.1 27 .9 24.8 25.3 25.9 26.5

DOO DOON 0.95 24.5 25.0 25.7 26.2 26.7 27 .3 27 .9

DRU D R U MLIN E 0 . 90 28.4 29.0 36.8 37 .3 38.0 38.6 39.3

DRY DRYBRIDG 0.96 58.5 59.8 61 .4 62.4 63.8 65.2 66.7

ENN ENNIS 0.96 55 .0 55 .8 56.8 57 .4 58.3 59.1 60.0

GAL GALWAY 0.97 112.7 69.1 71 .0 72.2 73.8 75 .4 77 .1

GCA GRANGE 0.99 46.1 46.9 48.1 48.8 49.7 50.7 51 .7

GI GREAT 0 .95 11 .1 11 .4 11 .7 11 .9 12 .2 12 .4 12.7

GIL GILRA 0.95 11 .9 11 .9 11 .9 11 .9 11 .9 11 .9 11 .9

GLA GLASMORE 0.97 26.2 26.8 27.5 27 .9 28.6 29.2 29.8

GLE GLENLARA 0.97 11 .2 11 .5 11 .8 12 .0 12.3 12 .5 12 .8

G RA G RA NG E 0 . 9 5 3 4 . 0 3 4 . 8 3 5. 7 3 6 .3 3 7 . 1 3 8. 0 3 8. 8

G RI G RI F F I NR 0 . 9 7 3 2. 8 33 . 5 3 4 .4 3 5. 0 3 5. 7 3 6 . 5 3 7 .3

GWE GORTAW EE 0.95 24.4 24.6 24.8 24.9 25.1 25 .3 25.5

HTS HARNETTS 0.99 - 6 .8 7 .0 7 .1 7 .2 7 .4 7 .5

IKE IKERRIN 0.92 19.5 20.0 20.5 20.8 21 .3 21 .8 22.3

KBY K ILBARRY 0.97 86.9 88.8 91 .3 92.8 94.9 96.9 99.1

KER KNOCKERA 0.94 25.4 25.9 26.7 27 .1 27 .7 28.3 28.9

K IN K INNEGAD 0.95 11 .7 11 .7 11 .7 11 .7 11 .7 11 .7 11 .7

KKY K ILKENNY 0.94 50.5 47 .5 48.8 49.6 50.8 51 .9 53.0

K L M K I L M O RE 0 . 9 6 3 7 . 2 3 7 . 6 3 8 . 0 3 8 . 2 3 8 . 6 3 8 . 9 3 9 .3


C-6



Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

KTL K ILTEEL 0 .92 28.9 29.6 30.4 30.9 31 .6 32.3 33.0

KTN K ILLOTER 0.95 13 .5 13 .8 14.1 14 .4 14.7 15 .0 15 .3

KU D KILMAHUD 0.95 23 .8 23 .8 23 .8 23 .8 23 .8 23 .8 23 .8

KU R KNOCKUMB 0.95 24.2 24.2 24.2 24.2 24.2 24.2 24.2

LA LANESBOR 0.94 11 .3 11 .6 11 .9 12 .1 12 .3 12 .6 12.9

LET LETTERKE 0.82 44.9 45.9 47.2 47.9 45.0 46.0 47.1

L IB L IBERTY 0 .97 15 .3 15 .7 16.1 16.3 16.7 17 .1 17 .5

L IM L IMERICK 0.97 58.3 59.6 61 .2 54.3 55 .5 56.7 58.0

L IS L ISDRUM 0.93 22.9 23.4 24.1 24.5 25.0 25.6 26.1

MAC MACROOM 0.84 14.4 7 .9 8 .2 4 .0 4 .1 4 .2 4 .3

MAL MALLOW 0.95 16.1 16.5 17 .0 17 .2 17 .6 18.0 18.4

MCE MACETOWN 0.96 25.3 25.8 26.3 26.7 27 .2 27.7 28.2

MID MIDLETON 0.97 23.1 23.6 24.2 24.6 25.2 25.8 26.3

MLN MULLAGHA 0.96 24.5 24.9 25.3 25.6 26.0 26.4 26.9

M O N M O N R E AD 0 . 9 7 1 3 . 0 1 3 .3 13 .7 13 .9 14.2 14.5 14 .8

MOY MOY 0.95 22.3 22.7 23 .4 23 .8 24.3 24.8 25.4

MR MARINA 0.97 19.6 20.0 20.6 20.9 21 .4 21 .8 22.3

MTH ME AT H 0. 89 32.0 32.7 33 .7 34.2 35 .0 35 .7 36.5

M U L M U L LI NG A 0 . 9 4 3 4 . 6 3 5. 3 3 6 .3 3 6 . 9 3 7 . 7 3 8. 6 3 9 .4

MU N MU NG RET 0.95 25.7 25.7 25.7 25.7 25.7 25.7 25.7

NAN NANGOR 0.95 26.0 26.0 26.0 26.0 26.0 26.0 26.0

NAV NAVAN 0.95 45.5 46.5 47 .8 48.6 49.7 50.8 51 .9

NEN NENAGH 0.95 - 21 .6 22.2 22.6 23.1 23.6 24.1

NEW NEW B RIDG 0 . 9 5 3 4 . 0 3 4 . 8 3 5. 8 3 6 .3 3 7 . 2 3 8. 0 3 8. 8

O L D O L D C OU R T 0 . 9 4 0 . 3 0 . 3 0 . 3 0 . 3 0 . 3 0 . 3 0 . 3

OUG OUGHTRAG 0.97 20.5 20.9 21 .5 21 .9 22.4 22.8 23 .4

PLA PLATIN 0 .95 54.6 54.6 54.6 54.6 54.6 54.6 54.6

P L S P O R T L AO I 0 . 9 3 3 8 . 9 3 3 . 9 3 4 .9 3 5 . 5 3 6 . 2 3 7 . 0 3 7 . 9

RAT RATHKEAL 0.93 25.5 26.1 26.8 27.2 27.8 28.4 29.1

R IC R ICHMOND 0.94 26.7 27 .3 28.1 28.5 29.2 29.8 30.5

RNW RINAWADE 0.95 15 .2 15 .2 15 .2 15 .2 15 .2 15 .2 15 .2

RSY R ING ASKI 0 .99 2 .1 2 .1 2 .2 2 .2 2 .3 2 .3 2 .4

RYB RYEBROOK 0.95 81 .0 81 .0 81 .0 81 .0 81 .0 81 .0 81 .0

SAL SALTHILL 0 .97 - 35 .5 36.5 37 .1 37 .9 38.8 39.6

SKL SHANKILL 0 .92 45.8 46.8 48.1 48.9 50.0 51 .1 52.2

SL I SL IGO 0.95 38.8 39.6 40.7 41 .4 42.3 43.3 44.2

SNG SINGLAND 0.96 8.9 9 .1 9 .4 9 .5 9 .7 9 .9 10.2

SOM SOMERSET 0 .95 20.1 20.6 21 .1 21 .5 22.0 22.4 22.9

STR STRATFOR 0.97 6 .0 6 .2 6 .3 6 .4 6 .6 6 .7 6 .9

SVN STEVENST 0.95 9 .7 9 .9 10.1 10.3 10.5 10.8 11 .0

TBG TRABEG 0.98 27.9 28.5 29.3 29.7 30.4 31 .1 31 .8

TBK TU LLABRA 0.93 7 .8 7 .9 8 .1 8 .3 8 .5 8 .6 8 .8

T H U T H U R L E S 0 . 9 2 3 5 . 4 3 6 . 2 37 .2 37 .8 38.6 39.5 40.4

T IP T IPPERAR 0.95 15 .6 15 .9 16.4 16.6 17 .0 17 .4 17 .8


C-7



Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

TLK TRILL ICK 0.99 15 .8 16.2 16.6 16.9 17 .3 17 .7 18.1

TON TONROE 0.92 12.6 12.9 13 .3 13 .5 13 .8 14.1 14 .4

TRI TR IEN 0.99 15 .5 15 .9 16.3 16.6 16.9 17 .3 17 .7

TRL TRALEE 0 .98 35.2 35 .9 36.9 37 .5 38.4 39.2 40.1

TSB THORNSBE 0.93 25.8 26.3 27 .1 27 .5 28.1 28.7 29.4

WAT WATERFOR 0.97 39.5 40.3 41 .5 42.1 43.1 44.0 45.0

WEX WEXFORD 0.95 40.8 41 .7 42.9 43.6 44.5 45.5 46.5

WHI WHITEG AT 0 .95 7 .0 7 .0 7 .0 7 .0 7 .0 7 .0 7 .0

CKM Carr ickmines 0 .95 204.4 208.9 214.7 23 7.2 242.1 247.0 252.0

F I N F ing las 0 .96 231 .7 236.4 242.5 246.2 223.7 256.6 261.8

I N C Inchicor e 0 .97 155.9 159.2 163.3 165.8 169.3 172.9 176.5

P B Pool beg 0.96 206.1 210.4 215 .9 219.2 223.7 228.4 233.2

TOTAL 3 6 23 3 6 81 3 7 7 6 3 859 3 9 0 6 4 0 0 9 4 0 85

Tabl e C-3 Demand Forecasts a t T ime of Summer Val ley


Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

AA ARDNACRU 0.95 33.2 26.0 26.7 27 .0 27 .6 28.3 29.0

AD AGHADA 1 .00 0.5 0 .5 0 .5 0 .6 0 .6 0 .6 0 .6

AHA AHANE 1 .00 1 .4 1 .5 1 .5 1 .5 1 .6 1 .6 1 .7

ANR ANNER 0.94 11 .0 11 .0 11 .0 11 .0 11 .0 11 .0 11 .0

ARI ARIG NA 0.87 2 .2 2 .3 2 .4 2 .4 2 .4 2 .5 2 .6

ARK ARKLOW 1 .00 11 .3 9 .1 9 .3 9 .4 9 .7 9 .9 10.2

ATH ATHLONE 0.99 15 .8 16.2 16.6 16.8 17 .2 17 .6 18.0

ATY ATHY 0.95 3 .0 5 .2 5 .4 5 .4 5 .6 5 .7 5 .8

BAL BALTRASN 0.98 8.0 8.1 8 .3 8 .4 8 .5 8 .7 8 .8

BAN BANDON 0.94 10.8 11 .1 11 .4 14.4 14.7 15 .1 15 .4

BAR BARRYMOR 0.99 8.2 8 .4 8 .6 8 .7 8 .9 9 .1 9 .3

BCM BALLYCU M 0.96 - - - 2 .9 3 .0 3 .1 3 .1

BDA BARODA 0.96 2 .0 2 .0 2 .0 2 .0 2 .0 2 .0 2 .0

B D N B ALLYDIN 0.95 5 .6 5 .7 5 .8 5 .8 5 .9 6 .0 6 .0

B EG B A L L YB EG 0 . 9 8 3 . 5 3 . 6 3 . 7 3 . 7 3 . 8 3 . 9 4 . 0

B IN BINBANE 0.95 6 .9 7 .1 7 .3 7 .4 4 .6 4 .7 4 .8

BK BELLACO R 0.97 1 .6 1 .6 1 .7 1 .7 1 .7 1 .8 1 .8

B L I B A L L Y L I C 0 . 9 9 3 . 0 3 . 1 3 . 2 3 . 2 3 .3 3 . 4 3 . 5

BLK BLAKE 0.98 8.1 8 .3 4 .8 4 .9 5 .0 5 .1 5 .2

B OG B A N OG E 0 . 9 5 - 4 .4 4 .5 4 .6 4 .7 4 .8 4 .9

BRI BRINNY 0.95 4 .2 4 .2 4 .2 4 .2 4 .2 4 .2 4 .2

BRY BARNAHEL 0.97 24.4 25.0 25.7 26.0 26.6 27.2 27 .9

BU N BU NB EG 0.95 - - - - 4 .4 4 .5 4 .6


C-8

Tabl e C-3 Demand Forecasts a t T ime of Summer Val ley (c ont inued)


Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

BUT BUTLERST 0.98 11 .2 11 .5 11 .8 11 .9 12 .2 12.5 12 .8

CAH CAHIR 0 .96 8.0 8 .1 8 .3 8 .4 8 .6 8 .8 9 .0

CBG CARROWBE 0.96 - 6 .2 6 .3 6 .4 6 .6 6 .7 6 .9

CBR CASTLEBA 0.91 17 .7 12 .0 12 .3 12 .5 12 .8 13 .1 13 .4

CF CATH_FAL 0 .95 4 .8 4 .9 5 .1 5 .1 5 .3 5 .4 5 .5

CFM CASTLEFA 0 .95 44.0 44.0 44.0 44.0 44.0 44.0 44.0

CHA CHARLEVI 0 .95 6 .1 6 .2 6 .4 6 .4 6 .6 6 .8 6 .9

CLN CLOON 0.97 8 .5 8 .7 9 .0 9 .0 9 .3 9 .5 9 .7

CLW CARLOW 0.99 11 .9 13 .7 17 .8 22.1 22.6 23.1 23.7

COL COLLEGE 0.96 31 .9 32.1 32.4 32.5 32.7 33.0 33.2

COS CARICKON 0.99 8.3 8 .5 8 .7 8 .8 9 .0 9 .2 9 .5

COW COW 0.99 9 .2 9 .4 9 .7 9 .8 10.0 10.3 10.5

CRA CRANE 0.97 9 .0 7 .2 7 .4 7 .5 7 .7 7 .9 8 .1

CRO COOLROE 1 .00 6 .0 6 .1 6 .3 6 .3 6 .5 6 .7 6 .8

CVW CASTLEVI 0 .97 10.6 10.8 11 .1 11 .3 11 .5 11 .8 12.1

DAL DALLOW 0.93 4 .7 4 .8 4 .9 5 .0 5 .1 5 .2 5 .3

DDK DU ND ALK 0.99 7 .8 8 .0 8 .2 8 .3 8 .5 8 .7 8 .9

DFR DUNFIRTH 0.96 1 .6 1 .7 1 .7 1 .7 1 .8 1 .8 1 .9

DGN DUNG ARVA 0.99 9 .2 9 .5 9 .7 9 .8 10.1 10 .3 10.6

DLT DALTON 0.98 7 .0 7 .1 7 .3 7 .4 7 .6 7 .8 8 .0

DMY DUNM ANWA 0.97 10.4 10.7 11 .0 9 .8 10.0 10.3 10.5

DOO DOON 0.99 8.9 9 .1 9 .3 9 .4 9 .7 9 .9 10.1

DRU DRUMLINE 0.98 11 .4 11 .7 19 .1 19 .2 19.5 19 .8 20.1

DRY DRYBRIDG 0.99 22.7 23 .2 23 .9 24.1 24.7 25.3 25.9

ENN ENNIS 0 .97 28.8 29.2 29.6 29.7 30.1 30.5 30.9

GAL GALWAY 1 .00 48.2 32.4 3 3 . 3 3 3 . 6 3 4 .4 3 5 . 3 3 6 . 1

G CA G RANG E 0.99 22.1 22.5 23 .0 23 .2 23 .6 24.0 24.5

GI GR EAT 0 . 93 3 .9 4 .0 4 .1 4 .1 4 .2 4 .3 4 .5

GIL GILRA 0.95 11 .9 11 .9 11 .9 11 .9 11 .9 11 .9 11 .9

GLA GLASMORE 1 .00 17 .2 17 .6 18.1 18.3 18.7 19 .2 19 .7

GLE GLENLARA 0. 90 3 .8 3 .9 4 .0 4 .0 4 .1 4 .2 4 .3

GRA GRANGE 0.96 17 .4 17 .8 18.3 18.5 18.9 19 .4 19 .9

GRI GRIFF INR 0.98 14.1 14 .5 14.9 15 .0 15 .4 15 .8 16.1

GWE GORTAW EE 0.95 19.7 19 .8 19.9 19.9 20.0 20.1 20.1

HTS HARNETTS 0.99 - 2 .5 2 .6 2 .6 2 .7 2 .7 2 .8

IKE IKERRIN 0.94 7 .0 7 .2 7 .4 7 .4 7 .6 7 .8 8 .0

KBY K ILBARRY 0.99 21 .5 22.0 22.6 22.8 23 .4 24.0 24.6

KER KNOCKERA 1 .00 12.6 13 .0 13 .3 13 .4 13 .8 14.1 14 .5

K IN K INNEGAD 0.95 4 .0 4 .0 4 .0 4 .0 4 .0 4 .0 4 .0

KKY K ILKENNY 0.98 17 .0 15 .9 16.3 16.5 16.9 17 .3 17 .7

KLM KILMORE 0.95 16.9 17 .1 17 .4 17 .5 17 .8 18.0 18.3

KTL K ILTEEL 0 .91 10.1 10.3 10.6 10.7 11 .0 11 .3 11 .5

KTN KILLOTER 0.95 5 .7 5 .8 6 .0 6 .1 6 .2 6 .4 6 .5


C-9



Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

KU R KNOCKUMB 0.95 24.2 24.2 24.2 24.2 24.2 24.2 24.2

LA LANESBOR 0.97 4 .2 4 .3 4 .5 4 .5 4 .6 4 .7 4 .8

LET LETTERKE 0.97 16.3 16.7 17 .2 17 .3 16.3 16.7 17 .1

L IB L IBERTY 0 .97 5 .6 5 .7 5 .9 5 .9 6 .1 6 .2 6 .4

L IM L IMERICK 1 .00 26.4 27.1 27 .8 25.2 25.8 26.5 27 .1

L IS L ISDRUM 0.95 8.3 8 .5 8 .7 8 .8 9 .0 9 .2 9 .5

MAC MACROOM 0.98 5 .9 3 .6 3 .7 2 .1 2 .2 2 .2 2 .3

MAL MALLOW 0.96 6.2 6 .4 6 .6 6 .6 6 .8 6 .9 7 .1

MCE MACETOWN 0.96 14.1 14 .3 14.6 14.7 14 .9 15 .2 15 .4

MID MIDLETON 0.98 14.7 15 .0 15 .4 15 .6 16.0 16.4 16.8

MLN MU LLAGHA 0.95 8.2 8 .4 8 .6 8 .6 8 .8 8.9 9 .1

MO N MO NREAD 0. 97 4 .3 4 .4 4 .5 4 .5 4 .7 4 .8 4 .9

MOY MOY 0.99 8.2 8 .4 8 .7 8 .7 9 .0 9 .2 9 .4

MR MARINA 0.97 7 .0 7 .2 7 .4 7 .4 7 .6 7 .8 8 .0

MTH MEATH 0.95 13 .6 13 .9 14.3 14 .4 14.8 15 .1 15 .5

MUL MULLINGA 0.98 11 .0 11 .3 11 .6 11 .7 12 .0 12 .3 12 .6

MUN MUNG RET 0.95 15 .0 15 .0 15 .0 15 .0 15 .0 15 .0 15 .0

NAN NANGOR 0.95 11 .0 11 .0 11 .0 11 .0 11 .0 11 .0 11 .0

NAV NAVAN 0.99 13 .7 14 .1 14 .5 14 .6 15 .0 15 .3 15 .7

NEN NENAGH 0.95 - 8 .0 8 .2 8 .3 8 .5 8 .7 8 .9

NEW NEWBRIDG 0.99 11 .3 11 .6 11 .9 12 .0 12 .3 12 .6 12 .9

O L D O L D C OU R T 0 . 9 4 0 . 3 0 . 3 0 . 3 0 . 3 0 . 3 0 . 3 0 . 3

OUG OUGHTRAG 1 .00 9 .4 9 .6 9 .9 10.0 10.2 10.5 10.7

PLA PLATIN 0.95 21 .0 21 .0 21 .0 21 .0 21 .0 21 .0 21 .0

PLS PORTLAOI 0 .96 14.8 13 .0 13 .4 13 .5 13 .9 14.2 14.5

RAT RATHKEAL 0 .96 9 .0 9 .2 9 .4 9 .5 9 .8 10.0 10.3

R IC R ICHMOND 0.99 9 .4 9 .6 9 .9 10.0 10.2 10.5 10.7

RNW RINAWADE 0.95 7 .6 7 .6 7 .6 7 .6 7 .6 7 .6 7 .6

RSY R INGASKI 0 .95 1 .0 1 .0 1 .1 1 . 1 1 . 1 1 . 1 1 . 1

RYB RYEBROOK 0.95 65.0 65.0 65.0 65.0 65.0 65.0 65.0

SAL SALTHILL 0 .97 - 13 .1 13 .5 13 .6 13 .9 14.3 14 .6

SKL SHANKILL 0 .96 16.2 16.6 17 .0 17 .2 17 .6 18.0 18.5

SL I SL IGO 0.99 14.9 15 .3 15 .7 15 .9 16.3 16.7 17 .1

S NG S I NG L A ND 0 . 9 6 3 .3 3 . 4 3 . 5 3 . 5 3 . 6 3 . 7 3 . 8

SOM SOMERSET 0 .98 7 .7 7 .9 8 .1 8 .1 8 .3 8 .6 8 .8

STR STRATFOR 1 .00 2 .3 2 .3 2 .4 2 .4 2 .5 2 .5 2 .6

SVN STEVENST 0.95 3 .6 3 .6 3 .7 3 .8 3 .9 4 .0 4 .1

TBG TRABEG 0.99 22.7 23 .2 23 .9 24.1 24.7 25.3 25.9

TBK TULLABRA 0.92 3 .9 4 .0 4 .2 4 .2 4 .3 4 .4 4 .5

THU THURLES 0.92 12.2 12 .5 12 .8 12 .9 13 .3 13 .6 13 .9

T IP T IPPERAR 0.98 6.0 6 .2 6 .3 6 .4 6 .6 6 .7 6 .9

TLK TRI L L I CK 0 . 9 4 3 . 7 3 . 8 3 . 9 3 . 9 4 . 0 4 . 1 4 . 2

TON TONROE 0.95 6 .1 6 .3 6 .4 6 .5 6 .7 6 .8 7 .0


C-10



Code Bus Name

P o w er

F a c t or 2010 2011 2012 2013 2014 2015 2016

TRI TR IEN 0.98 8.8 9 .0 9 .3 9 .4 9 .6 9 .8 10.1

TRL TRALEE 0 .99 13 .8 14.1 14 .5 14.6 15 .0 15 .4 15 .7

TSB THORNSBE 0.97 8 .4 8 .6 8 .8 8 .9 9 .1 9 .3 9 .5

WAT WATERFOR 0.95 12.9 13 .3 13 .6 13 .8 14.1 14 .4 14.8

WEX WEXFORD 0.99 14.6 14.9 15 .3 15 .5 15 .9 16.3 16.7

WHI WHITEG AT 0.95 2 .5 2 .5 2 .5 2 .5 2 .5 2 .5 2 .5

TR I TR IEN 0.98 8.8 9 .0 9 .3 9 .4 9 .6 9 .8 10.1

TRL TRALEE 0 .99 13 .8 14.1 14 .5 14.6 15 .0 15 .4 15 .7

TSB THORNSBE 0.97 8 .4 8 .6 8 .8 8 .9 9 .1 9 .3 9 .5

WAT WATERFOR 0.95 12.9 13 .3 13 .6 13 .8 14.1 14 .4 14.8

WEX WEXFORD 0.99 14.6 14.9 15 .3 15 .5 15 .9 16.3 16.7

WHI WHITEG AT 0.95 2 .5 2 .5 2 .5 2 .5 2 .5 2 .5 2 .5

CKM Carr ickmines 0 .96 94.7 97 .0 99.7 119.7 122.2 124.7 127.2

F I N F ing las 0 .96 100.4 102.7 105.3 106.3 108.7 111 .2 113 .8

I N C Inchicor e 0 .98 78.1 79.8 81 .7 82.4 84.2 86.0 87.9

P B Pool beg 0 . 97 93.9 96.0 98.4 99.3 101 .5 103.8 106.1

TOTAL 1638 1666 1709 1745 1779 1813 1848

Generation caPacity and disPatch detailsD.1 Generation connected to the transmission system

D.2 wind Generation connected to the distribution system

D.3 Generation dispatch details

APPENDIX D


D-1

APPENDIX D GENERATION CAPACITY AND DISPATCH DETAILS

D.1 GENERATION CONNECTED TO THE TRANSMISSION SYSTEM

Ta b le D - 1 l is ts ex i st i ng an d commi t ted future generat i on and the contract ed maximum

export capac i ty (MEC) o f each uni t . Table D-2 presents th e maximum cont inuous rat ing

(MCR) o f ea ch uni t at year end for ea ch year up to 2016. Al l generat ion capac i ty f igures in

Table D-1 and Table D-2 are expressed in expor te d t e r m s i . e . , g e n e ra t i on u n i t o u t p ut l e ss

the uni t ’s ow n auxi l iar y load. The uni ts ar e grouped in these tabl es on a geog raphical

b as is .


D-2

T a b l e D - 1 M ax i m u m E xp o rt C a pa ci t i e s o f Ex is t i ng and Commi t t ed Tr ansmiss ion-Connected G enerat i on

Area Generation Station Unit ID Connected At Fuel Type Maximum Export Capacity (MW)

Dublin Bay Power DB1 Irishtown 220 kV Gas 415.0

Huntstown HNC Huntstown 220 kV Gas 352.0

Huntstown HN2 Corduff 220 kV Gas 412.0

North Wall NW4 North Wall 220 kV Gas/DO 163.0

North Wall NW5 North Wall 220 kV Gas/DO 109.0

Poolbeg PB1 Poolbeg 220 kV Gas/HFO 109.5

Poolbeg PB2 Poolbeg 220 kV Gas/HFO 109.5

Poolbeg PBC Shellybanks 220 kV Gas/DO 460.0

Turlough Hill TH1 Turlough Hill 220 kV Hydro 73.0



Dublin


Dublin Area Total 2422.0

Aghada AD1 Aghada 220 kV Gas 258.0

Aghada AT1 Aghada 220 kV Gas/DO 90.0



Aghada CCGT ADC Longpoint 220 kV Gas 431.0

Athea - Athea 110 kV Wind 51.0

Athea Extension - Athea 110 kV Wind 22.0

Aughinish SK3 Sealrock 110 kV Gas 65.0

Aughinish SK4 Sealrock 110 kV Gas 65.0

Boggeragh - Boggeragh 110 kV Wind 57.0

Clahane - Clahane 110 kV Wind 37.8

Cloghboola - Knocknagashel 110 kV Wind 46.0

Coomacheo - Garrow 110 kV Wind 41.2

Coomacheo Extension - Garrow 110 kV Wind 18.0

Coomagearlahy - Coomagearlahy 110 kV Wind 42.5

Coomagearlahy Extension - Coomagearlahy 110 kV Wind 38.5

Dromada - Dromada 110 kV Wind 46.0

Glanlee - Glanlee 110 kV Wind 29.8

Glanlee Extension - Glanlee 110 kV Wind 6.0

Knockacummer - Knockacummer 110 kV Wind 87.0

Lee Hydro LE1 Inniscarra 110 kV Hydro 15.0

Lee Hydro LE2 Inniscarra 111 kV Hydro 4.0

Lee Hydro LE3 Carrigadrohid 110 kV Hydro 8.0

Marina MRT Marina 110 kV Gas/DO 85.0

Moneypoint MP2 Moneypoint 380 kV Coal 287.5

South-West

Moneypoint - Moneypoint 110 kV Wind 21.9


D-3

T a b l e D - 1 M ax i m u m E xp o rt C a pa ci t i e s o f Ex is t i ng and Commi t t ed Tr ansmiss ion-Connected G enerat i on (c ont i nued)


Tarbert TB1 Tarbert 110 kV HFO 54.0




South- West (Cont.)

Whitegate CCGT WG Glanagow 220 kV Gas 445.0

South-West Area Total 3067.6

Ardnacrusha AA1,2,3,4 Ardnacrusha 110 kV Hydro 86.0

Booltiagh - Booltiagh 110 kV Wind 19.5

Booltiagh Extension - Booltiagh 110 kV Wind 12.0

Derrybrien DBW Derrybrien 110 kV Wind 59.5

Keelderry - Keelderry 110 kV Wind 29.75



Mid-West

Tynagh TY Tynagh 220 kV Gas 404.0

Mid-West Area Total 1185.8

Ballywater BWW Ballywater 110 kV Wind 42.0

Castledockrill - Castledockrill 110 kV Wind 41.4

Great Island GI1 Great Island 110 kV HFO 54.0



Liffey LI1 Pollaphuca 110 kV Hydro 15.0



South-East

Nore Power NO1 Nore 110 kV Gas 98.0

South-East Area Total 431.4

Edenderry Power ED1 Cushaling 110 kV Peat 121.5

Edenderry PCP ED3 Cushaling 110 kV Distillate 58.0

Edenderry PCP ED5 Cushaling 110 kV Distillate 58.0

Lisheen - Lisheen 110 kV Wind 55.0

Rhode PCP RP1 Derryiron 110 kV Distillate 51.8

Rhode PCP RP2 Derryiron 110 kV Distillate 51.8

Midlands

West Offaly Power WO4 Shannonbridge 110 kV Peat 141.0

Midlands Area Total 537.1

Erne ER3 Cathaleen’s Fall 110 kV Hydro 22.5

Erne ER4 Cathaleen’s Fall 110 kV Hydro 22.5

Erne ER1 Cliff 110 kV Hydro 10.0

Erne ER2 Cliff 110 kV Hydro 10.0

North-West

Golagh GOL Golagh 110 kV Wind 15.0


D-4

T a b l e D - 1 M ax i m u m E xp o rt C a pa ci t i e s o f Ex is t i ng and Commi t t ed Tr ansmiss ion-Connected G enerat i on (c ont i nued)


Garvagh - Garvagh 110 kV Wind 58.225

Kingsmountain - Cunghill 110 kV Wind 34.8

Lough Ree Power LR4 Lanesboro 110 kV Peat 94.0

Meentycat - Meentycat 110 kV Wind 84.96

North- West (Cont.)

Mulreavy - Mulreavy 110 kV Wind 82.0

North-West Area Total 434.0

Ballakelly BY Ballakelly 220 kV Gas 445.0

Mountain Lodge - Ratrussan 110 kV Wind 30.6 North-East

Bindoo - Ratrussan 110 kV Wind 70.0

North-East Area Total 545.6 Tabl e D-2 Maximum Cont inuous Rat ing of Ex ist ing and Commit ted Tr ansmiss ion-Connect ed G enerat i on

Maximum Continuous Rating (Exported MW) Area

Generation Station

Unit ID 2010 2011 2012 2013 2014 2015 2016

Dublin Bay Power DB1 403.0 403.0 403.0 403.0 403.0 403.0 403.0

Huntstown HNC 343.0 343.0 343.0 343.0 343.0 343.0 343.0

Huntstown HN2 400.0 400.0 400.0 400.0 400.0 400.0 400.0

North Wall NW4 163.0 163.0 163.0 163.0 163.0 163.0 163.0

North Wall NW5 109.0 109.0 109.0 109.0 109.0 109.0 109.0

Poolbeg PB1 109.5 - - - - - -

Poolbeg PB2 109.5 - - - - - -

Poolbeg PBC 460.0 460.0 460.0 460.0 460.0 460.0 460.0

Turlough Hill TH1 73.0 73.0 73.0 73.0 73.0 73.0 73.0

Turlough Hill TH2 73.0 73.0 73.0 73.0 73.0 73.0 73.0

Turlough Hill TH3 73.0 73.0 73.0 73.0 73.0 73.0 73.0

Dublin

Turlough Hill TH4 73.0 73.0 73.0 73.0 73.0 73.0 73.0

Dublin Area Total 2389.0 2170.0 2170.0 2170.0 2170.0 2170.0 2170.0

Aghada AD1 258.0 258.0 258.0 258.0 258.0 258.0 258.0

Aghada AT1 90.0 90.0 90.0 90.0 90.0 90.0 90.0

Aghada AT2 90.0 90.0 90.0 90.0 90.0 90.0 90.0

Aghada AT4 90.0 90.0 90.0 90.0 90.0 90.0 90.0

Aghada CCGT ADC 430.0 430.0 430.0 430.0 430.0 430.0 430.0

Athea - 51.0 51.0 51.0 51.0 51.0 51.0 51.0

Athea Extension - 22.0 22.0 22.0 22.0 22.0 22.0 22.0

Aughinish SK3 80.4 80.4 80.4 80.4 80.4 80.4 80.4

Aughinish SK4 80.4 80.4 80.4 80.4 80.4 80.4 80.4

Boggeragh - 57.0 57.0 57.0 57.0 57.0 57.0 57.0

Clahane - 37.8 37.8 37.8 37.8 37.8 37.8 37.8

Cloghboola - - - - - 46.0 46.0 46.0

Coomacheo - 41.225 41.225 41.225 41.225 41.225 41.225 41.225

South-West

Coomacheo Ext. - 18.0 18.0 18.0 18.0 18.0 18.0 18.0


D-5

Tabl e D-2 Maximum Cont inuous Rat ing of Ex ist ing and Commit ted Tr ansmiss ion-Connect ed G enerat i on (c ont i nued)

Maximum Continuous Rating (Exported MW) Area Generation Station Unit ID

2010 2011 2012 2013 2014 2015 2016

Coomagearlahy - 42.5 42.5 42.5 42.5 42.5 42.5 42.5

Coomagearlahy Extension - 38.5 38.5 38.5 38.5 38.5 38.5 38.5

Dromada - 46.0 46.0 46.0 46.0 46.0 46.0 46.0

Glanlee - 29.8 29.8 29.8 29.8 29.8 29.8 29.8

Glanlee Extension - 6.0 6.0 6.0 6.0 6.0 6.0 6.0

Knockacummer - 87.0 87.0 87.0 87.0 87.0 87.0 87.0

Lee Hydro LE1 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Lee Hydro LE2 4.0 4.0 4.0 4.0 4.0 4.0 4.0

Lee Hydro LE3 8.0 8.0 8.0 8.0 8.0 8.0 8.0

Marina MRT 85.0 85.0 85.0 85.0 85.0 85.0 85.0

Moneypoint MP2 281.5 281.5 281.5 281.5 281.5 281.5 281.5

Moneypoint1 - - - - - - - -

Tarbert TB1 54.0 54.0 54.0 54.0 54.0 54.0 54.0

Tarbert TB2 54.0 54.0 54.0 54.0 54.0 54.0 54.0

Tarbert TB3 240.7 240.7 240.7 240.7 240.7 240.7 240.7

Tarbert TB4 240.7 240.7 240.7 240.7 240.7 240.7 240.7

South- West (Cont.)

Whitegate CCGT WG 440.6 440.6 440.6 440.6 440.6 440.6 440.6

South-West Area Total 3019.1 3019.1 3019.1 3019.1 3065.1 3065.1 3065.1

Ardnacrusha AA1,2,3,4 86.0 86.0 86.0 86.0 86.0 86.0 86.0

Booltiagh - 19.5 19.5 19.5 19.5 19.5 19.5 19.5

Booltiagh Extension - 12.0 12.0 12.0 12.0 12.0 12.0 12.0

Derrybrien - 59.5 59.5 59.5 59.5 59.5 59.5 59.5

Keelderry - 29.8 29.8 29.8 29.8 29.8 29.8 29.8

Moneypoint MP1 281.5 281.5 281.5 281.5 281.5 281.5 281.5

Moneypoint MP3 281.5 281.5 281.5 281.5 281.5 281.5 281.5

Mid-West

Tynagh TY 382.0 382.0 382.0 382.0 382.0 382.0 382.0

Mid-West Area Total 1151.8 1151.8 1151.8 1151.8 1151.8 1151.8 1151.8

Ballywater BWW 42.0 42.0 42.0 42.0 42.0 42.0 42.0

Castledockrill - 41.4 41.4 41.4 41.4 41.4 41.4 41.4

Great Island GI1 54.0 54.0 54.0 54.0 54.0 54.0 54.0

Great Island GI2 54.0 54.0 54.0 54.0 54.0 54.0 54.0

Great Island GI3 108.0 108.0 108.0 108.0 108.0 108.0 108.0

Liffey LI1 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Liffey LI2 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Liffey LI4 4.0 4.0 4.0 4.0 4.0 4.0 4.0

South-East

Nore Power NO1 - 98.0 98.0 98.0 98.0 98.0 98.0

South-East Area Total 333.4 431.4 431.4 431.4 431.4 431.4 431.4

Edenderry Power ED1 118.3 118.3 118.3 118.3 118.3 118.3 118.3

Edenderry PCP ED3 58.0 58.0 58.0 58.0 58.0 58.0 58.0

Edenderry PCP ED5 58.0 58.0 58.0 58.0 58.0 58.0 58.0

Lisheen - 55.0 55.0 55.0 55.0 55.0 55.0 55.0

Rhode PCP RP1 51.8 51.8 51.8 51.8 51.8 51.8 51.8

Rhode PCP RP2 51.8 51.8 51.8 51.8 51.8 51.8 51.8

Midlands

West Offaly Power WO4 137.0 137.0 137.0 137.0 137.0 137.0 137.0

Midlands Area Total 529.9 529.9 529.9 529.9 529.9 529.9 529.9

1 There is currently no set date for the connection of Moneypoint wind farm.


D-6

Tabl e D-2 Maximum Cont inuous Rat ing of Ex ist ing and Commit ted Tr ansmiss ion-Connect ed G enerat i on (c ont i nued)

Maximum Continuous Rating (Exported MW) Area Generation Station Unit ID

2010 2011 2012 2013 2014 2015 2016

Erne ER3 22.5 22.5 22.5 22.5 22.5 22.5 22.5

Erne ER4 22.5 22.5 22.5 22.5 22.5 22.5 22.5

Erne ER1 10.0 10.0 10.0 10.0 10.0 10.0 10.0

Erne ER2 10.0 10.0 10.0 10.0 10.0 10.0 10.0

Golagh - 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Garvagh - 58.2 58.2 58.2 58.2 58.2 58.2 58.2

Kingsmountain - 34.8 34.8 34.8 34.8 34.8 34.8 34.8

Lough Ree Power LR4 91.0 91.0 91.0 91.0 91.0 91.0 91.0

Meentycat - 85.0 85.0 85.0 85.0 85.0 85.0 85.0

North-West

Mulreavy - - - - 82.0 82.0 82.0 82.0

North-West Area Total 349.0 349.0 349.0 431.0 431.0 431.0 431.0

Ballakelly BY - - 445.0 445.0 445.0 445.0 445.0

Mountain Lodge MLW 30.6 30.6 30.6 30.6 30.6 30.6 30.6 North-East

Bindoo RRW 70.0 70.0 70.0 70.0 70.0 70.0 70.0

North-East Area Total 100.6 100.6 545.6 545.6 545.6 545.6 545.6

Total 7872.7 7751.7 8196.7 8278.7 8324.7 8324.7 8324.7

D.2 WIND GENERATION CONNECTED TO THE DISTRIBUTION SYSTEM

T a b l e D - 3 l is t s t h e t ot al c a p ac i t y o f w i n d g e n era t i o n th a t cur r e nt l y f e eds i nt o e ac h 1 1 0 k V

t ransmi ss ion s tat ion, f rom the di s t r ibut ion system. Table D-3 a l so show s the capac i ty o f

f u t u re w i n d g e n e r at io n u p t o 2 0 1 6 , b a s e d o n t h e wi n d f arms t h at c urr e n t l y h av e s ig n e d

connect ion ag reements wi th the DSO (as at the beginning of Ju ly 2009) .

Tabl e D-3 Ex is t ing and Commit ted Dist r ibut ion-Connected Wind Farm Capaci ty

W i n d F a r m C a p a c i t y ( M W ) A r e a

1 1 0 k V S t a t i o n

2009 2010 2011 2012 2013 2014 2015 2016

Ballylickey 28.1 36.5 36.5 36.5 36.5 36.5 36.5 38.5

Bandon 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5

Boggeragh - 44.0 44.0 44.0 44.0 44.0 44.0 44.0

Charleville 3.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0

Cordal - - - - - 94.0 94.0 94.0

Dungarvan 1.7 1.7 1.7 1.7 1.7 1.7 1.7 1.7

Dunmanway 45.3 45.3 45.3 45.3 45.3 45.3 45.3 45.3

Garrow - 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Glenlara 36.5 36.5 36.5 36.5 36.5 36.5 36.5 59.0

Hartnett's Cross - 9.0 9.0 9.0 9.0 9.0 9.0 9.0

Kilbarry - 0.9 0.9 0.9 0.9 0.9 0.9 0.9

Knockearagh 13.9 13.9 13.9 13.9 13.9 13.9 13.9 13.9

South-West

Knocknagashel - - - - - 32.6 32.6 32.6


D-7

Tabl e D -3 Ex i s t i ng and Commi t t ed D ist r i but i o n-Connected Wind Farm Capaci ty (c ont inued)


1 1 0 k V S t a t i o n

2009 2010 2011 2012 2013 2014 2015 2016

Macroom 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Midleton 1.7 1.7 1.7 1.7 1.7 1.7 1.7 1.7

Muingnaminnane - - - - - - - 42.4

Oughteragh - 9.0 9.0 9.0 9.0 9.0 9.0 9.0

Rathkeale 12.5 32.5 32.5 32.5 32.5 32.5 32.5 32.5

Tralee 62.9 64.6 64.6 64.6 64.6 64.6 64.6 64.6

South- West (Cont.)

Trien 51.4 53.1 53.1 53.1 53.1 53.1 53.1 53.1

South-West Area Total 276.4 386.0 386.0 386.0 386.0 512.5 512.5 579.4

Ardnacrusha 10.9 10.9 10.9 10.9 10.9 10.9 10.9 10.9

Ennis - 24.0 24.0 24.0 24.0 24.0 24.0 24.0

Galway 4.6 4.6 4.6 4.6 4.6 4.6 4.6 4.6

Nenagh - 6.5 6.5 6.5 6.5 6.5 6.5 6.5

Somerset 7.7 7.7 7.7 7.7 7.7 7.7 7.7 7.7

Mid-West

Tullabrack 12.6 12.6 12.6 12.6 12.6 12.6 12.6 12.6

Mid-West Area Total 35.8 66.2 66.2 66.2 66.2 66.2 66.2 66.2

Arklow 25.2 25.2 25.2 25.2 25.2 25.2 25.2 25.2

Butlerstown 1.7 1.7 1.7 1.7 1.7 1.7 1.7 1.7

Carlow 34.7 34.7 34.7 34.7 34.7 34.7 34.7 34.7

Crane 4.9 7.4 7.4 7.4 7.4 7.4 7.4 7.4

Great Island 4.3 4.3 10.3 10.3 10.3 10.3 10.3 10.3

Lodgewood - 27.5 45.9 45.9 45.9 45.9 45.9 45.9

South-East

Wexford 38.9 38.9 38.9 38.9 38.9 38.9 38.9 38.9

South-East Area Total 109.7 139.6 164.0 164.0 164.0 164.0 164.0 164.0

Athlone - 4.3 4.3 4.3 4.3 4.3 4.3 4.3

Cauteen - - - 25.0 25.0 95.0 95.0 95.0

Dallow 6.8 6.8 6.8 6.8 6.8 6.8 6.8 6.8

Ikerrin 5.1 6.0 8.5 8.5 8.5 8.5 8.5 8.5

Midlands

Lanesboro 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0

Midlands Area Total 16.9 22.0 24.5 49.5 49.5 119.5 119.5 119.5

Arigna 16.4 16.4 16.4 16.4 16.4 16.4 16.4 16.4

Bellacorick 6.5 6.5 6.5 6.5 6.5 6.5 6.5 6.5

Binbane 46.3 46.3 46.3 46.3 46.3 46.3 46.3 46.3

Castlebar 24.2 43.8 43.8 43.8 43.8 43.8 43.8 43.8

Cathaleen's Fall 5.4 5.4 5.4 5.4 5.4 5.4 5.4 5.4

Corderry 32.1 41.1 41.1 41.1 41.1 41.1 41.1 41.1

Dalton 2.6 2.6 2.6 2.6 2.6 2.6 2.6 2.6

Glenree - - 62.2 62.2 62.2 62.2 62.2 62.2

Letterkenny 41.9 45.3 45.3 45.3 45.3 45.3 45.3 45.3

Moy 6.0 6.0 6.0 6.0 6.0 6.0 6.0 6.0

North- West

Mulreavy - 3.6 7.9 7.9 7.9 7.9 7.9 7.9


D-8

Tabl e D -3 Ex i s t i ng and Commi t t ed D ist r i but i o n-Connected Wind Farm Capaci ty (c ont inued)


1 1 0 k V S t a t i o n

2009 2010 2011 2012 2013 2014 2015 2016

Sorne Hill 61.2 61.2 61.2 61.2 61.2 61.2 61.2 61.2

Tonroe 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 North- West (Cont.) Trillick 23.8 34.0 34.0 34.0 34.0 34.0 34.0 34.0

North-West Area Total 275.7 321.5 387.9 387.9 387.9 387.9 387.9 387.9

Drybridge 4.2 4.2 4.2 4.2 4.2 4.2 4.2 4.2

Dundalk 8.0 8.0 8.0 8.0 8.0 8.0 8.0 8.0

Meath Hill 15.0 15.0 15.0 15.0 15.0 15.0 15.0 15.0

Navan 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0

North-East

Shankill 6.0 6.0 6.0 6.0 6.0 6.0 6.0 6.0

North-East Area Total 38.2 38.2 38.2 38.2 38.2 38.2 38.2 38.2

Totals 752.6 973.5 1066.9 1091.9 1091.9 1288.4 1288.4 1355.3

F igure D-1 displays the geograph ica l locat ion o f a l l ex i st i ng and p l a nned w i nd f a r ms and t h e

t o t al at e ac h 1 1 0 k V st at ion t h e y f e e d i n t o . M W c ap a c i t i e s sh ade d r e d c o rres p o n d t o ex i s t i n g

w i n d f ar m s and b l u e c or re s p o n d t o c om m i t te d w i nd f ar m s .

S ince the Ju ly 2009, three new c onv ent i onal g enerat i on p l ant s , Cui l leen 9 8.4 MW O CG T

p lant a t Ath lone, Co. Westmeath, Sui r 98 MW OCGT pl ant a t Cahi r , Co. T ipperary and

C a u l st o w n 5 8 M W O C G T P e a ki n g P l ant a t C a u l st ow n , C o . L o u t h a s w el l a s o n e 7 0 M W pum p e d

storage pl ant a t Knocknag reenan, Co. Cork , have s ig ned non-f i rm connect ion ag reements .

A s i n di c at e d i n th e p r opo s e d d i r e ct ion p u b l i sh ed by the CER ent i t led “Proposed Di rect ion on

Convent ional Of fer Issuance Cr i ter ia” (Reference: CER/09/114 ) , i t i s ex pected that the f i rm

a c c e ss d a t es f o r th e s e p l a nt s w i l l b e d e t e r mi ne d a s p a r t o f t h e G at e 3 g r o u p p r oc e s si n g

s c h e m e f or gen e r a t or s .


D-9

F igure D-1 Geograph ica l Locat ion of Ex is t ing and P lanned Wind Farms at Ju ly 01 s t 2009


D-10

D.3 GENERATION DISPATCH DETAILS

T a b l e D - 4 l i s t s t h e g e n er a t i o n d ispatch prof i les us ed for the purposes o f the TFS 2010-2016

shor t c i rcui t anal yses and demand opportuni ty analysis .

The S V column r epr esents the di spatch at summer val ley and WP denotes the wint er peak

d i s p at ch . Wi n d f ar m s w e r e di s pa tc h e d a t 3 5% o f th e i r r a t e d c a pa ci t y , wh i ch e q u a t es

a p p r ox i ma t el y t o t h ei r av e r a g e e x pec t e d o ut p ut . The values show n are in expor ted terms

i .e . , they are net o f each generat ion uni t 's ow n consumpt ion. They indicate the power

d e l i v er e d t o t h e g r i d .

I n a l l i n s t a nc e s , ex c ep t t h e di s p at ch p r o f i l e s u sed f o r t he win t e r pea k sho r t c i r c ui t s tu d i e s ,

a d i sp a tc h o f 0 M W i nd i c at s t ha t t h e u n i t is not synchronised to the syst em and i s

e f f e ct iv el y of f . F o r t h e ca l c ul at ion s o f s h or t c i rcu i t c ur r e nt s a t wi n t er p ea k s , a l l g e ner a t or s

not d i spatched ar e model led as synchronised to the syst em and d ispatched at zero MW.

I t sh ould be noted that s tat ion dema nd proj ect ions are developed f rom the system demand

f ore cas ts on a top -d own bas i s , us ing a forecast o f t ransmi ss ion losses. The t ransmissi on

l o s s f i g ur e s c a l c ul a t e d by t h e n et w ork m o d e l s u sed in th is TFS may d i f f er f rom the forecast

f ig u res a n d hen c e the disp atc h totals may di f fer f r o m t h e s y st e m d e m a n d f o r ec a st s i n T a b l e

3 -1 i n Ch a pter 3 .


D-11

Table D-4 Dispatch Prof i les - Sh or t C i rc ui t and Demand Opportuni ty Anal ys es

Area Generation Station Unit ID 2010 2013 2016

SV SP WP SV SP WP SV SP WP

Dub

lin

Dublin Bay Power DB1 163 280 300 180 280 410 150 340 400

Huntstown HN1 0 200 300 160 0 280 0 150 350

Huntstown HN2 257 260 300 0 310 380 0 360 380

North Wall NW4 0 0 0 0 0 0 0 0 0

North Wall NW5 0 0 0 0 0 0 0 0 0

Poolbeg PBC 0 75 240 0 0 0 0 0 0

Turlough Hill TH1,2,3,4 -210 14 17 -210 61 56 -210 4 46

Embedded Hydro - 0 0 0 0 0 4 0 0 4

Dublin Area Total 210 829 1157 130 651 1130 -60 854 1180

Sou

th-W

est

Aghada AD1 0 0 0 0 0 0 0 0 0

Aghada AT1 0 0 0 0 0 0 0 0 0

Aghada AT2 0 0 0 0 0 0 0 0 0

Aghada AT4 0 0 0 0 0 0 0 0 0

Aghada CCGT ADC 0 280 400 250 380 420 260 390 430

Athea - 18 18 18 18 18 18 18 18 18

Athea Extension - 8 8 8 8 8 8 8 8 8

Aughinish SK3 81 81 81 81 81 81 81 81 81

Aughinish SK4 81 81 81 81 81 81 81 81 81

Boggeragh - 20 20 20 20 20 20 20 20 20

Clahane - 13 13 13 13 13 13 13 13 13

Cloghboola - - - - - - - 16 16 16

Coomacheo - 14 14 14 14 14 14 14 14 14 Coomacheo Extension

- 6 6 6 6 6 6 6 6 6

Coomagearlahy - 15 15 15 15 15 15 15 15 15 Coomagearlahy Extension

- 13 13 13 13 13 13 13 13 13

Dromada - 16 16 16 16 16 16 16 16 16

Glanlee - 10 10 10 10 10 10 10 10 10

Glanlee Extension - 2 2 2 2 2 2 2 2 2

Knockacummer - 30 30 30 30 30 30 30 30 30

Lee Hydro LE1,2 0 0 4 0 0 4 0 0 15

Lee Hydro LE3 0 0 8 0 0 8 0 0 8

Marina MRT 0 0 0 0 0 0 0 0 0

Moneypoint MP2 0 260 280 0 240 290 0 240 260

Moneypoint - - - - - - - - - -

Tarbert TB1 0 30 0 0 0 0 0 0 40

Tarbert TB2 0 30 0 0 0 0 0 0 0

Tarbert TB3 0 150 200 0 0 200 0 0 240

Tarbert TB4 0 0 240 0 0 0 0 0 240

Whitegate CCGT WG 100 280 200 300 380 420 330 390 430

Embedded Wind - 111 111 135 135 135 135 179 179 203

South-West Area Total 541 1471 1797 1015 1465 1807 1115 1545 2212


D-12

Table D-4 Dispatch Prof i les - Sh or t C i rcui t an d Demand Opportuni ty Anal ys es (c ont inued)

Area Generation Station Unit ID 2010 2013 2016

SV SP WP SV SP WP SV SP WP

Mid

-Wes

t

Ardnacrusha AA1,2,3,4 0 0 86 0 0 86 0 0 86

Booltiagh - 7 7 7 7 7 7 7 7 7 Booltiagh Extension

- 4 4 4 4 4 4 4 4 4

Derrybrien - 21 21 21 21 21 21 21 21 21

Keelderry - 10 10 10 10 10 10 10 10 10

Moneypoint MP1 19 260 280 35 240 290 31 240 260

Moneypoint MP3 0 260 280 0 240 290 0 240 260

Tynagh TY 0 295 280 0 0 155 0 0 0

Embedded Wind - 13 13 23 23 23 23 23 23 23

Mid-West Area Total 73 870 991 100 545 886 97 545 671

Sou

th-E

ast

Ballywater - 15 15 15 15 15 15 15 15 15

Castledockrill - - - 14 14 14 14 14 14 14

Great Island GI1 0 0 0 0 0 0 0 0 0

Great Island GI2 0 0 0 0 0 0 0 0 0

Great Island GI3 0 0 0 0 0 0 0 0 0

Liffey Hydro LI1,2,4 0 0 34 0 0 34 0 0 34

Nore Power NO1 - - - 0 0 50 0 0 70

Embedded Wind - 39 39 49 57 57 57 57 57 57

South-East Area Total 54 54 112 87 87 171 87 87 191

Mid

land

s

Edenderry Power ED1 130 130 0 130 130 130 130 130 130

Edenderry PCP ED3, ED5 0 0 0 0 0 0 0 0 0

Lisheen - 19 19 19 19 19 19 19 19 19

Rhode PCP RP1, RP2 0 0 0 0 0 0 0 0 0

West Offaly Power WO4 150 150 150 150 150 150 150 150 150

Embedded Wind - 8 8 8 17 17 17 42 42 42

Midlands Area Total 307 307 177 317 317 317 341 341 341

Nor

th-W

est

Erne ER3,4 0 0 45 0 0 45 0 0 45

Erne ER1,2 0 0 20 0 0 20 0 0 20

Golagh - 5 5 5 5 5 5 5 5 5

Garvagh - 20 20 20 20 20 20 20 20 20

Kingsmountain - 12 12 12 12 12 12 12 12 12

Lough Ree Power LR4 100 100 100 100 100 100 100 100 100

Meentycat - 30 30 30 30 30 30 30 30 30

Mulreavy - - - - 29 29 29 29 29 29

Embedded Wind - 113 113 113 136 136 136 136 136 136

North-West Area Total 280 280 345 332 332 397 332 332 397

Nor

th-E

ast

NI Import - 222 -14 137 -150 -52 -445 -188 -229 -438

Ballakelly BY - - - 0 260 350 225 370 380

Mountain Lodge - 11 11 11 11 11 11 11 11 11

Bindoo - 25 25 25 25 25 25 25 25 25

Embedded Wind - 13 13 13 13 13 13 13 13 13

North-East Area Total 271 35 186 -101 257 -46 86 190 -9

East-West Interconnector Import - - - 0 400 400 0 400 400

Totals 1736 3845 4765 1879 4053 5061 1997 4294 5382

short circuit currentsE.1 background

E.2 analysis

E.3 results

APPENDIX E


E-1

APPENDIX E SHORT CIRCUIT CURRENTS

E.1 BACKGROUND

S h o rt c i rc u i t c ur r e nt l e v el s ar e c a l c ul a t e d in a c c or d a nc e wi th the U K E ngi ne e r i ng

R e c o m m e n da t i o n G 74 , w h i ch i s a c o m p u t er ba s e d a n al y si s b a s e d o n t h e I nt e r na t i o na l

Standard IEC60909.

T h e p l ot i n F i g ur e E - 1 s ho w s a t y p ic al s h or t c i rc ui t c ur r e nt . S h o rt c i r c ui t c u r re n t i s mad e u p

of an AC component wi th a s l ow decay rate , a n d a D C c o mp o n e n t i l l u st r at e d b y the g re e n

l i n e wi th a m u c h f a st er d e c a y r at e .

F ig u re E - 1 Typ i cal Short C i r c ui t Curr ent

T h e D C c o mp o n e n t o f a s h or t c i r cui t c u rr e n t dec a y s ex p o nen t i a l l y . I t s r at e o f d ec a y i s

i n f l u e n c e d by t h e r at io o f t h e r e a cta n c e ( X ) t o t h e res is t a nc e ( R ) o f t he p a t hs b a ck t o t h e

g e n e ra t or s fe e d i ng p ow er t o t he fa u l t ( th e X / R r at i o ) .

T h e r e ac ta n c e c o m p o n ent b e c o m e s l e s s d o mi n ant f u r t h er out o n t he gr i d a w a y f r om m a j o r

generat ion in feeds. Consequent ly the X/R rat io decreases and the rate o f decay o f the DC

component is much faster . The faster decayi ng DC component resul ts in a smal ler o f fset

appl ied to the tota l root mean square (RMS) break current .

T h e sh or t c i rc u i t c ur r e nt t h at a c i rc u i t b r eak e r i s e x p e ct e d t o i n t er r u pt d ur i ng a f a ul t is th e

R M S o f A C c u r r e nt o f f s et b y a D C c u r r e n t a n d i s re f e rr e d t o as t h e t ot al R M S b r e a k c ur r e n t .

T h e f a ul t b re a k i ng c u rr ent r a t i n g i s l i mi t ed b y the thermal energy th at the c i rcu i t breaker

c a n d i s si p ate d u r i ng t he t i m e th e c o n t a ct s take to separat e . The peak make cur rent is

h igh e r th a n t h e b r e ak c ur r e n t a n d i s t h e m o s t o ne r o u s c o n d i t i o n th at a c i r c ui t br e a k er c a n

be exposed to . Th is wi l l occur wh en a c i rcu i t breaker is c losed onto an ear thed i tem of

e q u i p m e nt e . g . b u s b a r , t r a n s mi s si on l i n e , t r a n sfo r m e r et c . A t t h i s i n st ant i n t i m e , th e D C

v al u e i s c l os e t o i t s m ax i m u m s o tha t th e t ot al c u rr e n t ( A C + D C ) i s a t i ts p e ak. Ci r cu i t

Time (ms)

Total RMS break current

Time for circuit breaker to clear

fault

Time between fault and circuit breaker contacts starting to

separate

Peak make current Current [kA]

Fault occurs at time t0


E-2

b r e a k er s ar e t y p ic al l y r at e d a p pr ox im a t el y 2 . 5 t i m e s h ig he r f o r p ea k ma k e th a n f or b r e a k

cur rents . In genera l , peak make current s are o f c o n c er n a t s t a t i o ns c l os e t o m a j o r

g enerat i on in f eeds.

The t ransmiss ion syst em is des igned and operated to mainta in RMS break shor t c i rcui t

leve ls in ac cordance wi th Gr id Code CC.8.6. A summary o f these requi rements is set out in

T a b l e E - 1 . I n d e si g ni n g th e s y s t e m, a 1 0 % sa f et y m a r gi n i s a pp l i e d .

I t should be noted that Gr id Code Versi on 3 .1 ( re l eased in May 2008) conta ins a

modi f i c at i on w hi ch st ipul at es t h at f au l t l ev e ls a t desig nat ed s t at i ons may be a l l ow ed t o

increase to 31 .5 kA. I f necessary , the equipment a t these s tat ions is to be modi f i ed or

r e pl a c e d i n o r d e r t o com p l y wi th th i s n e w r a t in g . T h e s t at i o n s c ur r e nt l y d e sig n a t ed f o r

operat ion o f the 110 kV equipment up to 31 .5 k A , a s p r o p o s ed b y t h e T S O , a r e; B ar na h el y ,

C o l l e g e P ar k, C o r d u f f , F in g l a s , K i l b ar r y , K n ockrah a, Louth, Mar ina, Raf feen and Trabeg. The

TS O wi l l an nual ly p ubl i sh an up dated l is t of des ignated st at ions.

T a b l e E - 1 Sho r t C i r c ui t Cur r e nt L ev el s - St a n d ar d E q u i p m e nt Ra t i ng

V o l t a g e L ev el St andard Equi pment Sh or t C i rc ui t Cur rent Rat ing

4 0 0 kV 50 kA

220 kV 4 0 k A

W it hi n t h e Dub l i n A re a 26 kA

O ut si de th e D ubl i n Ar ea 25 kA 110 kV

Desi gn at ed s i tes 3 1 . 5 kA

Recent connect ions of addi t ional generat ion t o t h e gr id h av e r a is e d con c e r n s a b out th e

pe ak - ma ke lev els i n some ar eas. Peak-make values ar e therefore inc l uded for completeness.

E.2 ANALYSIS

T h e g e ner at i o n d i sp a tch e s u s ed i n t h e sh or t c i r cu i t a n al ys i s ar e sh ow n i n T a bl e D - 4 i n

Appendix D. In the case o f the wi nter peak st udies , however , a l l generators that were not

o r i g i na l l y d i s p a t c h e d as i n T a b l e D -4 w e r e s wi tch e d i n a n d d i s p at ch e d a t o u t p ut s of 0 M W

and 0 Mvar .

T h e d e m a n d a t ea ch t ra n s m i s si o n i n t er f ac e sta t i o n i s a s su m e d t o c on t r i b ut e 1 M V A o f

i n d u c t i o n mot o r f a ul t i nf e e d p er M W o f l o a d. An X/R rat io o f 2 .76 is assumed for these

l oa ds, in accor d an ce wi th the Engi n eer ing Recommendat ion G74.

T h e t ot al RM S b r ea k c ur r e n t d e p e nds u p o n t h e c i r c ui t br e ak e r b re a k t im e i . e . , th e t i m e i t

t a kes f or the pr ot ec t i on t o oper at e and f or th e c i rc u i t br eaker c ont ac ts to f u l l y separat e . A

c i rcu i t breaker break t ime of 50 ms was ass um e d f o r th e c i rc u i t b r ea k e r s l o ca t ed a t th e

220 kV s tat ions and a break t ime of 80 ms was appl ied to the 110 kV st at ions. Thes e break


E-3

t i m e s ar e de e m e d t o b e a p pr o p r i at e i n th e ca s e o f t he m aj or i t y o f c i rc u i t b re a k er s on t he

network.

T h e t ot al R MS b r e a k c ur re n t a t a b u sba r i s a n i nd i c at i o n of th e s ho rt c i rc u i t l ev el tha t o n e

c o u l d ex p e ct a t th a t p oint i n t h e n et w o rk . H o w ev e r , t h e y d o n o t n e c e s sa r i l y r ep r e se n t t h e

s h o rt c i r c ui t c ur r e nt t h at c o ul d f l o w th r o ugh each i n di v i d u al br e a k er , wh ich m a y b e l ow e r .

E.3 RESULTS

Tables E -2 to E -4 l is t to ta l RMS break cur rents , peak make cur rent s and X/R rat ios for

s ingle -phase to ear th and balanc ed three- ph ase faul ts for gr id busbars . These are

presented for maximum winter peak and minimum summer va l l ey system demand condi t ions

for 2010, 2013 and 2016 .

Ta b le E - 2 Sho r t C i r c ui t Cur r ent s for M a ximum and Minimum Demand in 20 10

Winter Peak 2010 Summer Val ley 2010

T h r e e -P h a s e S ingle-P hase T h r e e -P h a s e S ingle-P hase

Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Adamstown 110 kV 13.6 29.8 11.7 6.8 33.0 14.0 9.5 28.6 11.2 5.8 30.8 13.3

Agannygal 110 kV 3.0 11.8 5.4 4.3 9.9 4.5 3.1 10.9 4.7 4.4 9.4 4.2

Aghada 110 kV 4.5 20.5 9.1 5.6 24.4 10.7 4.8 16.4 7.0 5.7 20.0 8.6

Aghada A 220 kV 10.6 19.4 7.7 12.5 20.5 8.5 8.8 9.4 3.7 9.8 11.7 4.8

Aghada B 220 kV 17.4 31.2 12.8 17.7 36.4 15.6 13.1 19.4 7.6 13.4 24.4 10.0

Aghada C 220 kV 17.4 31.2 12.8 17.7 36.4 15.6 13.1 19.4 7.6 13.4 24.4 10.0

Aghada D 220 kV 12.1 21.8 8.7 14.0 22.9 9.6 8.8 9.4 3.7 9.7 12.0 4.9

Ahane 110 kV 4.5 27.8 12.3 5.3 24.1 10.7 4.6 19.9 8.4 5.4 18.5 8.0

Anner 110 kV 2.7 11.3 5.9 4.0 7.6 3.6 2.9 9.9 5.0 4.0 7.2 3.4

Ardnacrusha 110 kV 5.4 34.2 14.4 6.6 35.9 15.2 4.9 22.4 9.2 5.8 26.4 11.2

Arigna 110 kV 3.9 14.9 6.3 5.1 11.1 4.9 3.9 13.5 5.5 5.1 10.3 4.4

Arklow 110 kV 8.3 20.9 8.1 9.2 25.5 10.2 9.2 18.0 6.8 10.0 22.2 8.7

Arklow 220 kV 9.1 19.2 7.7 10.3 18.0 7.5 8.9 15.0 6.0 10.1 14.5 6.0

Arva 110 kV 3.1 17.5 8.3 4.3 13.3 6.1 3.2 16.3 7.4 4.3 12.4 5.7

Athea 110 kV 6.6 17.9 6.2 8.6 15.4 6.0 7.3 16.0 5.0 9.2 14.6 5.4

Athlone 110 kV 3.5 15.6 7.4 4.7 10.1 4.6 3.6 14.6 6.8 4.7 9.8 4.4

Athy 110 kV 3.1 12.2 6.1 4.3 9.8 4.6 3.1 9.5 4.7 4.3 7.9 3.7

Aughinish 110 kV 7.7 24.0 9.5 9.8 26.4 10.5 8.1 20.8 7.9 10.0 24.2 9.5

Ballybeg 110 kV 8.9 15.8 6.3 9.3 18.7 7.6 9.3 14.1 5.5 9.6 16.9 6.8

Ballydine 110 kV 2.9 13.1 6.7 4.2 10.1 4.7 3.1 11.3 5.5 4.2 9.2 4.3

Ballylickey 110 kV 2.7 5.7 2.9 4.0 3.9 1.8 2.8 5.3 2.5 4.0 3.6 1.7

Ballywater 110 kV 4.4 12.9 5.5 3.1 11.8 5.8 3.6 7.4 3.4 3.6 7.9 3.8

Baltrasna 110 kV 6.1 23.5 10.0 7.3 18.8 7.9 6.3 20.7 8.7 7.4 17.2 7.2

Bandon 110 kV 3.0 12.2 6.0 4.4 10.7 5.0 3.2 11.0 5.1 4.4 10.1 4.6


E-4

Table E -2 Short C i rcui t Current s for Maxi mum and Minimum Demand in 20 10 (cont inued)



Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Banoge 110 kV 3.6 12.7 5.8 4.6 11.3 5.1 - - - - - -

Barnahely A 110 kV 4.3 27.2 12.1 5.1 28.3 12.6 6.3 28.0 10.9 6.6 32.9 13.5

Barnahely B 110 kV 6.1 28.4 11.7 6.9 28.8 12.1 - - - - - -

Baroda 110 kV 4.0 18.0 8.4 4.9 21.1 9.5 4.2 15.1 6.8 5.0 18.4 8.2

Barrymore 110 kV 3.5 16.2 7.8 4.8 9.9 4.5 3.7 13.1 6.0 4.8 8.7 3.9

Bellacorick 110 kV 3.1 7.9 3.7 4.2 8.1 3.8 2.7 6.1 2.9 3.6 6.8 3.2

Binbane 110 kV 3.2 6.9 2.9 4.7 6.9 3.0 3.2 6.2 2.5 4.6 6.5 2.8

Blake 110 kV 3.9 16.8 7.9 5.0 12.0 5.4 4.1 14.5 6.6 5.1 11.0 4.9

Boggeragh 110 kV 7.0 19.0 7.5 7.6 11.8 4.9 6.9 15.3 5.8 7.5 10.4 4.3

Booltiagh 110 kV 3.1 8.6 4.2 4.4 8.0 3.7 3.2 7.8 3.8 4.5 7.7 3.5

Brinny A 110 kV 2.9 10.9 5.4 4.2 9.1 4.3 3.1 9.9 4.7 4.3 8.6 3.9

Brinny B 110 kV 2.9 10.9 5.4 4.2 9.2 4.3 3.0 9.9 4.7 4.3 8.6 4.0

Butlerstown 110 kV 4.4 22.6 10.0 4.7 21.8 9.9 4.4 16.8 7.4 4.6 17.6 8.0

Cahir 110 kV 2.9 14.7 7.4 4.2 9.4 4.4 3.1 12.9 6.3 4.3 9.2 4.3

Carrick-on-Shannon 110 kV 4.1 24.7 10.6 5.0 27.0 11.9 4.3 22.2 9.1 5.1 24.5 10.5

Carlow 110 kV 5.4 19.6 8.5 6.1 19.7 8.5 5.3 16.5 7.1 6.0 17.4 7.5

Carrickmines B 110 kV 23.3 35.7 14.4 20.3 38.4 15.5 20.4 29.4 11.5 18.0 32.9 13.1

Carrickmines 220 kV 15.0 48.4 19.7 10.3 54.8 22.4 13.3 33.5 13.3 9.6 40.1 16.3

Carrigadrohid 110 kV 4.7 29.5 12.4 5.7 24.7 10.6 5.1 22.6 8.8 5.9 20.8 8.7

Carrowbeg 110 kV 2.7 5.8 2.9 4.0 5.5 2.6 - - - - - -

Cashla 110 kV 6.2 36.4 15.1 7.1 45.4 19.0 5.9 28.3 11.4 6.6 36.4 15.1

Cashla 220 kV 7.7 26.4 10.8 9.9 26.2 10.9 7.5 18.2 7.3 9.2 20.0 8.2

Castlebar 110 kV 3.2 10.3 4.8 4.6 9.7 4.4 3.2 8.9 4.1 4.5 8.2 3.7

Castledockrill 110 kV 7.0 19.9 7.3 4.6 21.5 9.3 - - - - - -

Castlefarm A 110 kV 7.0 22.8 9.1 8.6 24.2 9.8 7.4 19.9 7.6 8.8 22.3 8.9

Castlefarm B 110 kV 7.0 22.8 9.1 8.6 24.2 9.8 7.4 19.8 7.6 8.8 22.2 8.8

Castleview 110 kV 3.7 27.3 12.7 4.5 20.4 9.4 4.1 20.5 8.9 4.7 16.7 7.5

Cathaleen's Fall 110 kV 4.3 19.4 7.3 5.3 19.0 7.9 3.7 14.7 5.5 4.6 16.1 6.7

Charleville 110 kV 3.7 14.1 6.3 5.1 9.8 4.4 3.3 11.6 5.2 4.6 8.7 3.9

Clahane 110 kV 4.4 20.4 7.8 5.9 17.8 7.4 4.8 16.8 5.7 6.2 15.6 6.2

Clashavoon A 110 kV 7.0 36.0 13.7 8.6 34.9 13.9 7.1 26.6 9.4 8.5 27.9 10.8

Clashavoon B 110 kV 7.0 36.0 13.7 8.6 34.9 13.9 7.1 26.6 9.4 8.5 27.9 10.8

Clashavoon 220 kV 9.0 21.5 8.6 10.6 20.5 8.5 9.3 14.0 5.3 10.5 15.0 6.1

Cliff 110 kV 4.2 15.1 6.0 5.1 13.7 5.9 3.6 11.6 4.6 4.5 11.9 5.1

Clonkeen A 110 kV 6.5 19.5 6.4 6.8 19.3 7.5 6.6 17.1 5.0 6.9 17.7 6.5

Cloon 110 kV 4.4 16.5 7.5 5.5 11.7 5.2 3.2 12.9 6.1 4.2 9.3 4.3

College Park 110 kV 8.7 43.9 17.5 6.7 46.6 19.8 8.5 35.1 13.8 6.9 39.1 16.4


E-5




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Coolroe 110 kV 3.3 21.1 9.9 4.6 20.0 9.1 3.5 16.2 7.2 4.6 16.8 7.5

Coomagearlahy 110 kV 6.9 16.6 5.2 7.8 17.8 6.6 7.1 15.0 4.3 7.9 16.7 5.9

Corderry 110 kV 4.0 16.1 6.3 5.6 14.8 6.2 4.1 14.4 5.4 5.5 13.6 5.6

Corduff A 110 kV 10.0 51.4 20.1 11.4 57.4 22.8 9.4 40.0 15.5 10.8 46.8 18.6

Corduff B 110 kV 10.0 51.4 20.1 11.4 57.4 22.8 9.4 40.0 15.5 10.8 46.8 18.6

Corduff 220 kV 16.7 61.8 25.3 15.7 70.2 29.7 13.3 35.0 14.0 13.7 44.5 18.6

Corraclassy 110 kV 3.7 13.2 5.9 4.9 10.7 4.8 3.7 12.5 5.4 5.0 10.2 4.5

Cow Cross 110 kV 4.0 27.4 12.4 4.6 23.3 10.6 4.7 22.7 9.5 5.0 20.6 9.1

Crane 110 kV 5.9 20.4 7.9 6.1 20.9 8.7 3.7 9.5 4.1 4.2 9.9 4.5

Cullenagh 110 kV 5.6 28.4 12.0 6.5 32.5 13.8 5.5 21.0 8.8 6.2 25.3 10.7

Cullenagh 220 kV 8.8 20.2 8.2 10.4 19.3 8.0 7.6 14.1 5.7 9.1 14.9 6.2

Cunghill 110 kV 3.0 10.5 4.7 4.4 9.8 4.4 2.9 8.7 3.8 4.1 8.8 3.9

Cushaling 110 kV 7.5 28.4 10.9 9.6 26.2 10.4 5.9 15.6 6.2 7.5 17.3 7.1

Dallow 110 kV 3.4 10.8 5.2 4.6 7.1 3.3 2.9 9.3 4.6 4.0 6.1 2.9

Dalton 110 kV 2.8 8.5 4.2 4.0 5.9 2.8 2.9 7.7 3.7 4.0 5.6 2.6

Derrybrien 110 kV 3.1 9.8 4.3 4.6 9.2 4.1 3.2 9.1 3.8 4.7 8.9 3.9

Derryiron 110 kV 6.6 19.6 8.1 8.3 19.4 8.0 5.6 9.5 4.2 6.6 11.5 4.9

Doon 110 kV 2.8 12.4 6.4 4.0 8.4 4.0 2.9 10.8 5.4 4.1 8.0 3.7

Dromada 110 kV 5.6 15.5 5.6 5.2 12.8 5.4 6.1 14.0 4.7 5.5 12.1 4.9

Drumkeen 110 kV 3.9 14.1 5.2 5.1 12.5 5.2 4.0 13.2 4.5 5.1 12.0 4.9

Drumline 110 kV 3.1 15.8 7.8 4.1 11.7 5.5 3.2 12.9 6.0 4.2 10.4 4.8

Drybridge 110 kV 5.6 29.8 12.8 6.6 25.6 10.9 5.8 26.4 11.1 6.8 23.4 9.9

Dundalk 110 kV 3.7 17.8 8.3 4.7 16.7 7.6 3.8 16.7 7.6 4.8 15.5 7.0

Dunfirth 110 kV 4.8 13.1 5.9 6.0 9.0 3.9 4.9 10.4 4.6 6.0 7.8 3.4

Dungarvan 110 kV 3.7 12.0 5.7 4.8 7.7 3.5 3.8 10.2 4.7 4.8 6.9 3.1

Dunmanway 110 kV 3.2 13.1 6.2 4.7 11.5 5.2 3.4 11.6 5.2 4.9 10.7 4.7

Dunstown 220 kV 11.4 46.9 18.8 10.8 43.6 18.1 11.8 33.9 13.3 11.2 34.6 14.2

Dunstown 400 kV 21.4 14.7 6.6 15.8 12.1 5.2 20.4 11.3 4.9 16.0 10.0 4.3

Ennis 110 kV 3.3 20.0 9.5 4.6 18.6 8.5 3.4 16.1 7.3 4.5 16.1 7.3

Fassaroe A 110 kV 5.5 18.3 7.9 5.8 13.7 6.0 5.7 16.2 6.9 5.9 12.7 5.5

Fassaroe B 110 kV 5.2 18.0 7.9 5.6 13.6 6.0 5.5 16.0 6.9 5.7 12.6 5.5

Finglas 220 kV 18.3 61.6 25.6 17.2 72.6 31.1 13.0 33.2 13.3 13.5 43.6 18.2

Kildonan 110 kV 6.6 33.6 14.1 5.5 28.9 12.7 6.7 27.9 11.5 5.7 25.4 11.1

Finglas A 110 kV 36.8 34.9 15.5 31.7 38.5 16.8 24.8 27.1 11.1 24.9 31.7 13.2

Finglas B 110 kV 37.7 37.5 16.6 32.8 45.7 20.0 24.9 27.3 11.2 24.8 34.9 14.5

Flagford 110 kV 4.4 26.3 11.2 5.4 31.9 13.8 4.6 23.6 9.5 5.5 28.8 12.1


E-6




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Flagford 220 kV 7.3 16.2 6.7 9.8 15.1 6.3 7.6 14.3 5.8 9.9 13.7 5.7

Galway 110 kV 4.3 25.4 11.5 5.1 26.9 12.0 4.4 20.8 9.0 5.1 22.9 10.1

Garrow A 110 kV 4.6 15.3 5.5 3.6 14.4 6.4 4.8 13.7 4.4 3.7 13.4 5.6

Garvagh 110 kV 4.5 13.4 5.0 6.3 12.3 5.0 4.6 12.1 4.4 6.3 11.3 4.6

Gilra 110 kV 3.1 12.8 6.2 4.0 10.5 4.9 3.1 11.8 5.5 4.0 9.7 4.5

Glanagow 220 kV 17.6 30.5 12.5 16.9 35.4 15.1 13.6 19.6 7.7 13.5 24.4 10.0

Glanlee 110 kV 6.8 16.0 5.1 7.2 17.1 6.4 7.0 14.4 4.2 7.3 16.0 5.7

Glasmore 110 kV 5.0 15.2 6.8 5.4 10.9 4.9 5.3 13.3 5.8 5.5 10.1 4.5

Glenlara A 110 kV 3.7 7.6 3.2 5.6 5.8 2.5 3.7 7.0 2.9 5.5 5.5 2.3

Golagh 110 kV 3.1 9.5 4.1 4.1 6.5 3.0 3.1 8.5 3.5 4.1 6.0 2.7

Gorman 110 kV 6.1 29.1 12.4 7.1 33.0 13.9 6.3 26.2 10.8 7.3 30.0 12.5

Gorman 220 kV 8.4 28.2 11.6 9.8 23.0 9.6 8.9 24.3 9.8 10.1 20.5 8.5

Gortawee 110 kV 3.8 12.7 5.8 5.4 10.9 4.8 3.9 12.0 5.3 5.4 10.5 4.6

Grange 110 kV 13.4 28.9 11.3 6.1 28.0 12.1 12.2 22.8 8.9 6.1 23.5 10.2

Grange Castle 110 kV 17.0 31.4 12.4 8.5 35.4 14.5 10.3 29.7 11.5 6.4 31.8 13.5

Great Island 110 kV 7.0 33.5 13.2 7.8 42.1 17.1 5.6 20.9 8.6 6.2 28.1 11.8

Great Island 220 kV 10.0 24.4 9.7 11.7 25.1 10.4 7.7 15.5 6.2 9.1 17.8 7.4

Griffinrath 110 kV 7.0 24.8 10.3 7.4 25.0 10.5 7.4 20.4 8.4 7.7 21.5 8.9

Hartnett's Cross 110 kV 3.7 20.7 9.4 4.7 15.4 6.9 - - - - - -

Huntstown A 220 kV 17.4 59.3 24.5 14.4 69.1 28.9 12.6 32.1 12.9 12.2 41.9 17.3

Huntstown B 220 kV 15.7 55.4 22.6 11.9 62.2 25.6 13.4 33.4 13.5 11.8 41.8 17.2

Ikerrin 110 kV 4.5 10.1 4.7 6.0 6.9 3.0 3.7 8.7 4.2 5.2 6.0 2.7

Inchicore A 220 kV 14.5 48.7 19.7 9.1 53.6 22.0 12.8 36.6 14.4 9.8 43.9 17.8

Inchicore B 220 kV 16.2 40.8 17.1 13.2 43.6 18.3 11.4 32.7 12.8 9.7 33.9 13.9

Inchicore A 110 kV 31.8 37.9 16.3 27.7 46.6 19.8 16.8 35.3 13.5 15.5 44.1 17.3

Inchicore B 110 kV 51.8 36.9 17.5 40.4 46.6 21.3 10.1 27.3 10.6 8.7 32.5 13.2

Inniscarra 110 kV 3.3 20.6 9.6 4.6 18.9 8.6 3.5 15.8 7.0 4.6 16.0 7.2

Irishtown 220 kV 16.7 52.5 21.5 14.6 61.1 25.6 13.8 36.1 14.2 12.6 44.9 18.4

Keelderry 110 kV 3.4 8.5 3.7 4.9 7.2 3.2 3.5 8.0 3.3 5.0 7.0 3.0

Kellis 110 kV 6.3 21.4 9.0 7.4 25.0 10.5 6.1 17.8 7.4 7.2 21.5 9.0

Kellis 220 kV 7.9 19.1 7.9 9.8 16.5 6.9 7.7 15.1 6.2 9.5 14.1 5.9

Kilbarry 110 kV 5.8 48.1 19.4 6.6 47.7 20.0 5.9 30.7 11.9 6.4 34.1 14.1

Kilkenny 110 kV 3.0 10.3 5.2 4.3 9.9 4.6 3.0 8.6 4.3 4.2 8.8 4.1

Killonan 110 kV 5.4 41.2 17.3 6.4 48.8 20.6 5.2 26.4 10.6 6.2 31.4 13.1

Killonan 220 kV 5.5 22.6 9.7 7.4 22.6 9.6 8.2 16.4 6.4 9.5 16.2 6.6

Killoteran 110 kV 4.8 24.6 10.7 4.7 24.8 11.2 4.6 17.8 7.7 4.6 19.5 8.8

Kilmahud 110 kV 13.8 29.7 11.6 6.9 32.8 13.9 9.1 28.1 11.0 5.6 29.7 12.9


E-7




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Kilmore 110 kV 17.7 30.9 12.2 11.8 33.1 13.2 13.7 23.5 9.1 9.8 26.4 10.7

Kilteel 110 kV 4.4 16.5 7.6 5.5 15.1 6.7 4.6 14.2 6.4 5.6 13.8 6.0

Kiltoy 110 kV 3.7 12.8 5.0 4.8 10.6 4.6 3.8 12.0 4.4 4.9 10.1 4.2

Kinnegad 110 kV 5.3 14.1 6.1 7.0 12.6 5.4 5.2 9.0 4.0 6.5 9.4 4.0

Knockacummer 110 kV 3.7 7.0 3.0 4.6 5.2 2.3 3.7 6.5 2.7 4.5 4.9 2.2

Knockearagh 110 kV 5.7 15.4 5.7 7.3 13.6 5.5 5.7 13.1 4.4 7.2 12.2 4.7

Knockraha A 110 kV 7.6 56.0 21.7 8.6 54.6 22.0 - - - - - -

Knockraha B 110 kV 7.6 56.0 21.7 8.6 54.6 22.0 7.0 33.3 12.6 7.7 35.4 14.2

Knockraha A 220 kV 9.0 29.9 11.7 9.9 32.0 13.2 9.6 14.1 5.5 10.1 17.0 6.9

Knockraha B 220 kV 11.2 23.5 9.4 12.1 23.3 9.7 10.0 16.4 6.4 10.8 17.4 7.2

Knockumber 110 kV 3.7 15.9 7.6 4.5 12.8 5.9 3.7 14.2 6.7 4.6 11.5 5.3

Lanesboro 110 kV 3.8 21.2 9.6 5.1 22.0 9.8 3.9 20.0 8.8 5.2 21.7 9.5

Letterkenny 110 kV 4.2 16.4 6.0 5.3 15.5 6.4 4.3 15.2 5.2 5.4 14.6 5.8

Liberty Street 110 kV 5.1 39.7 16.6 4.4 40.4 18.3 5.3 26.4 10.6 4.7 29.9 13.1


Limerick 110 kV 4.7 34.8 15.1 5.6 33.1 14.4 4.8 24.1 9.9 5.6 25.3 10.8

Lisdrum 110 kV 2.7 9.7 4.9 3.8 6.4 3.1 2.8 9.2 4.5 3.9 6.2 3.0

Lisheen 110 kV 3.6 7.8 3.7 5.1 5.7 2.6 3.5 7.1 3.4 5.0 5.4 2.4

Lodgewood 110 kV 8.7 23.2 8.3 9.1 28.6 11.1 - - - - - -

Lodgewood 220 kV 9.3 18.3 7.2 10.7 17.9 7.4 - - - - - -

Longpoint 220 kV 12.2 21.8 8.7 14.4 22.9 9.7 8.7 9.3 3.7 9.7 11.9 4.9

Louth 110 kV 10.4 44.3 16.9 11.2 55.5 21.8 10.9 40.1 14.8 11.5 49.3 19.1

Louth 220 kV 9.4 44.4 17.9 10.6 43.1 18.0 10.3 38.6 15.2 11.3 37.2 15.4

Macetown 110 kV 7.0 37.2 15.4 7.0 36.0 15.2 7.1 30.5 12.4 7.1 31.0 13.0

Macroom 110 kV 5.1 31.8 13.0 6.2 27.2 11.5 5.5 24.1 9.1 6.4 22.7 9.3

Mallow 110 kV 3.5 13.7 6.5 5.2 11.7 5.2 3.5 11.6 5.3 5.0 10.5 4.7

Marina 110 kV 6.0 45.9 18.4 6.8 49.4 20.5 5.9 29.2 11.4 6.4 34.8 14.3

Maynooth A 110 kV 11.1 33.1 13.0 11.9 40.2 16.0 11.3 26.2 10.2 11.9 32.8 13.0

Maynooth B 110 kV 8.3 40.5 16.3 10.2 38.5 15.5 8.7 32.5 12.8 10.4 32.7 13.1

Maynooth A 220 kV 10.8 41.0 16.5 11.2 37.4 15.6 10.4 31.2 12.3 11.0 30.5 12.6

Maynooth B 220 kV 10.4 49.9 19.9 10.4 44.6 18.5 10.8 35.2 13.8 10.9 35.2 14.5

Meath Hill 110 kV 3.2 13.2 6.3 4.6 11.8 5.4 3.3 12.4 5.8 4.6 11.2 5.1

Meentycat 110 kV 3.7 12.0 4.5 5.2 10.9 4.5 3.8 11.4 4.0 5.2 10.6 4.3

Midleton 110 kV 3.4 22.5 10.7 4.6 18.5 8.5 3.9 17.4 7.8 4.8 15.5 6.9

Moneypoint G1 400 kV 26.0 18.6 8.5 20.3 18.3 8.2 19.8 12.4 5.3 18.1 13.9 6.1

Moneypoint G2 400 kV 31.5 10.4 4.9 25.4 10.8 5.0 14.5 5.0 2.1 15.0 6.2 2.6


E-8




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Moneypoint G3 400 kV 26.0 18.6 8.5 20.3 18.3 8.2 19.8 12.4 5.3 18.1 13.9 6.1

Moneypoint 110 kV 2.7 4.7 2.5 3.9 3.5 1.7 2.7 4.4 2.2 3.9 3.3 1.6

Moneypoint A 220 kV 13.3 26.0 10.5 11.0 24.5 10.1 9.0 13.2 5.1 8.9 15.2 6.2

Moneteen 110 kV 5.0 25.0 10.8 6.0 19.3 8.3 5.1 19.4 8.0 6.1 16.1 6.9

Monread 110 kV 4.1 16.0 7.5 5.0 15.5 7.0 4.3 13.8 6.3 5.1 13.9 6.2

Moy 110 kV 3.9 9.6 4.3 5.0 10.7 4.7 2.7 5.9 2.8 3.3 7.3 3.5

Mullagharlin 110 kV 3.7 18.6 8.7 4.7 17.5 7.9 3.9 17.4 7.9 4.8 15.6 7.0

Mullingar 110 kV 2.7 8.2 4.3 3.8 9.1 4.4 2.8 7.6 3.9 3.8 8.7 4.1

Mungret A 110 kV 4.7 23.4 10.3 5.8 17.8 7.8 4.9 18.4 7.7 5.9 15.0 6.4

Mungret B 110 kV 4.7 23.5 10.3 5.8 17.8 7.8 4.9 18.4 7.7 5.8 15.0 6.4

Nangor 110 kV 14.8 30.3 11.9 7.2 33.5 14.1 9.5 28.7 11.2 5.7 30.2 13.1

Navan 110 kV 5.2 25.2 11.1 6.1 25.7 11.2 5.0 21.6 9.4 5.8 21.8 9.4

Nenagh 110 kV 2.6 7.0 3.7 3.8 4.4 2.1 - - - - - -

Newbridge 110 kV 4.2 21.3 9.7 5.1 20.9 9.4 4.4 17.3 7.7 5.2 18.1 8.0

North Wall 220 kV 16.9 56.4 23.1 9.8 59.9 24.4 12.4 30.8 12.3 9.8 37.8 15.5

Oldcourt A 110 kV 3.6 22.2 10.4 4.3 17.4 8.1 4.1 18.8 8.2 4.6 15.6 7.1

Oldcourt B 110 kV 3.6 22.4 10.5 4.4 17.6 8.2 4.1 19.0 8.3 4.6 15.8 7.1

Oldstreet 220 kV 15.4 27.1 11.3 13.2 28.6 12.0 12.4 16.6 6.8 11.8 19.7 8.2

Oldstreet 400 kV 19.3 18.2 7.9 13.4 17.0 7.2 15.5 12.3 5.1 12.8 13.1 5.5

Oughtragh 110 kV 3.7 10.6 4.7 4.9 7.0 3.1 3.6 8.5 3.5 4.8 6.1 2.7

Platin 110 kV 5.0 26.4 11.7 5.7 20.7 9.1 5.1 23.6 10.2 5.8 19.0 8.3

Pollaphuca 110 kV 3.3 6.1 3.0 4.8 5.4 2.5 2.8 4.6 2.4 4.0 4.7 2.2

Poolbeg A 110 kV 27.9 31.3 13.2 23.1 38.3 15.8 22.2 28.4 11.3 19.0 35.1 14.1

Poolbeg B 110 kV 27.9 31.3 13.2 23.0 38.3 15.8 22.2 28.4 11.3 19.0 35.1 14.0

Poolbeg A 220 kV 17.4 56.4 23.3 10.8 62.9 25.7 12.9 31.1 12.5 10.6 39.3 16.1

Poolbeg B 220 kV 17.3 40.9 17.4 15.1 45.4 19.3 12.5 35.2 13.8 10.1 40.5 16.5

Portlaoise 110 kV 3.9 18.1 8.5 5.4 15.3 6.8 3.9 15.4 7.0 5.3 13.9 6.1

Prospect 220 kV 12.0 32.7 12.9 10.8 30.8 12.7 8.5 15.9 6.1 8.7 18.5 7.5

Raffeen 220 kV 12.7 29.1 11.5 12.5 31.8 13.1 10.9 18.8 7.3 11.0 22.2 9.1

Raffeen A 110 kV 5.1 33.0 14.0 5.9 38.7 16.6 7.1 30.9 11.7 7.5 39.3 15.8

Raffeen B 110 kV 7.5 34.2 13.5 8.4 39.6 16.0 - - - - - -

Rathkeale 110 kV 3.5 15.6 7.4 4.6 9.5 4.4 3.6 12.6 5.7 4.6 8.4 3.8

Ratrussan 110 kV 3.4 14.6 6.2 4.4 16.4 7.3 3.5 13.8 5.6 4.5 16.0 6.9

Richmond A 110 kV 2.9 10.3 5.1 4.0 7.5 3.5 3.0 9.7 4.7 4.1 7.1 3.4

Richmond B 110 kV 2.9 10.2 5.1 4.3 9.8 4.6 3.0 9.6 4.7 4.3 9.4 4.3

Rinawade 110 kV 5.0 23.4 10.4 6.0 16.9 7.4 5.2 19.5 8.5 6.1 15.1 6.5


E-9




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Ringaskiddy 110 kV 5.4 26.9 11.4 5.9 26.0 11.2 5.3 24.4 9.9 5.5 25.2 10.8

Ryebrook 110 kV 5.3 29.4 12.9 6.0 20.6 9.0 5.5 24.3 10.4 6.1 18.3 7.9

Sealrock 110 kV 7.5 23.5 9.3 9.2 25.9 10.4 7.8 20.5 7.8 9.5 23.8 9.4

Sealrock 110 kV 7.5 23.5 9.3 9.2 25.9 10.4 7.8 20.5 7.8 9.5 23.8 9.4

Shankill 110 kV 3.1 15.1 7.0 4.2 14.4 6.6 3.2 14.2 6.3 4.3 13.6 6.1

Shannonbridge 110 kV 5.8 36.9 15.0 7.4 42.0 17.2 6.2 34.4 13.3 7.8 40.0 16.0


Shellybanks A 220 kV 17.0 56.2 23.1 10.7 62.9 25.7 12.7 31.0 12.4 10.5 39.3 16.1

Shellybanks B 220 kV 16.1 51.1 20.8 13.5 59.3 24.6 13.2 35.0 13.8 11.8 43.5 17.7

Singland 110 kV 5.5 34.5 14.5 6.4 33.6 14.3 5.1 23.1 9.4 6.1 24.6 10.3

Sligo 110 kV 3.3 16.1 6.9 4.6 14.6 6.5 3.3 13.8 5.6 4.5 13.2 5.8

Somerset 110 kV 3.0 15.4 7.6 4.0 10.7 5.1 3.1 14.3 6.8 4.1 10.0 4.7

Sorne Hill 110 kV 3.3 6.2 2.5 3.9 7.3 3.2 3.4 5.9 2.3 4.0 7.1 3.1

Srananagh 110 kV 3.6 17.7 7.3 4.8 15.2 6.7 3.6 15.1 6.0 4.7 13.7 5.9

Stevenstown 110 kV 4.7 12.4 5.6 5.1 8.5 3.8 4.9 11.1 5.0 5.2 8.0 3.6

Stratford 110 kV 3.4 8.8 4.3 4.4 6.9 3.2 3.1 7.2 3.6 4.2 6.2 2.9

Tynagh 110 kV 6.5 23.3 9.8 2.3 19.3 10.5 5.7 21.8 9.3 2.2 18.3 10.0

Tarbert 110 kV 12.3 54.8 19.0 14.3 51.9 19.8 8.0 30.6 10.5 9.6 34.8 13.1

Tarbert 220 kV 14.2 39.1 15.4 15.8 44.0 18.6 8.7 17.4 6.5 9.7 22.7 9.1

Tawnaghmore 110 kV 3.7 8.1 3.6 5.0 8.3 3.7 2.6 5.0 2.4 3.3 5.8 2.8

Tawnaghmore 110 kV 3.8 8.2 3.7 5.1 8.6 3.8 2.6 5.0 2.4 3.3 6.0 2.9

Thornsberry 110 kV 4.8 14.7 6.5 6.1 13.6 5.9 3.6 5.5 2.6 4.5 6.2 2.9

Thurles 110 kV 3.9 10.0 4.7 5.9 8.6 3.8 3.7 9.0 4.2 5.6 8.2 3.6

Tipperary 110 kV 2.6 10.7 5.6 3.8 6.8 3.3 2.7 9.4 4.8 3.9 6.3 3.0

Tonroe 110 kV 2.7 6.7 3.3 3.9 4.4 2.1 2.8 6.2 3.0 3.9 4.1 1.9

Trabeg 110 kV 5.7 44.4 18.0 5.9 47.0 20.0 5.8 28.8 11.3 5.9 33.8 14.1

Tralee 110 kV 5.0 23.4 8.9 6.3 19.4 8.0 4.7 16.4 5.7 5.9 14.8 5.9

Trien A 110 kV 5.5 24.0 8.6 7.1 20.9 8.3 6.2 20.2 6.5 7.6 18.9 7.2

Trillick 110 kV 3.4 6.7 2.7 4.0 7.3 3.2 3.4 6.4 2.4 4.1 7.0 3.0

Tullabrack 110 kV 2.7 5.1 2.6 4.0 3.8 1.8 2.8 4.7 2.4 4.0 3.6 1.7

Turlough Hill 220 kV 11.4 31.0 12.4 12.7 27.2 11.4 11.5 24.4 9.7 12.7 23.2 9.7

Tynagh 220 kV 15.2 30.9 12.6 17.4 33.9 14.6 10.1 16.0 6.4 11.3 20.3 8.4

Waterford 110 kV 5.6 27.9 11.6 6.0 28.2 12.1 5.1 19.4 8.2 5.5 21.5 9.3

Wexford 110 kV 3.9 14.6 6.2 5.2 13.3 5.8 3.6 10.1 4.3 4.7 10.3 4.5

Whitegate 110 kV 4.3 22.0 9.9 5.1 22.8 10.2 4.6 17.3 7.5 5.3 18.9 8.3

Woodland 220 kV 12.1 55.2 22.1 11.6 52.8 21.9 12.0 35.9 14.2 11.9 38.8 16.0

Woodland 400 kV 21.8 16.5 7.4 21.2 17.2 7.8 19.0 12.1 5.2 19.5 13.6 6.0


E-10

Tabl e E -3 Shor t C i r c ui t Cur r ent s f or Maximum and Minimum Demand in 2013 Winter Peak 2013 Summer Val ley 2013


B u s X/R

R a t i o

P e a k M a k e [kA]

Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

Adamstown 110 kV 13.7 40.4 15.8 6.6 41.7 17.8 13.6 33.6 12.8 7.0 35.8 15.0

Agannygal 110 kV 3.0 11.9 5.4 4.3 9.9 4.5 3.1 11.2 4.9 4.3 9.5 4.3

Aghada 110 kV 4.5 20.7 9.2 5.6 24.6 10.7 4.7 16.9 7.4 5.6 20.6 9.0

Aghada A 220 kV 10.5 20.0 8.0 12.5 21.0 8.8 7.9 12.2 5.0 9.3 14.5 6.0

Aghada B 220 kV 16.9 32.4 13.2 15.8 38.3 16.1 12.2 21.0 8.3 12.2 26.4 10.9

Aghada C 220 kV 16.9 32.4 13.2 15.8 38.3 16.1 12.2 21.0 8.3 12.2 26.4 10.9

Aghada D 220 kV 12.0 22.8 9.2 13.9 23.8 10.0 12.2 19.2 7.6 13.9 21.2 8.9

Ahane 110 kV 4.5 28.5 12.7 5.3 24.4 10.8 4.6 23.9 10.4 5.3 21.5 9.5

Anner 110 kV 2.7 11.5 6.0 4.0 7.6 3.6 2.8 10.3 5.2 4.0 7.2 3.4

Ardnacrusha 110 kV 5.4 35.0 14.8 6.6 37.0 15.6 5.0 26.5 11.2 6.0 30.4 13.0

Arigna 110 kV 4.7 17.0 7.1 6.0 13.1 5.6 4.9 15.5 6.2 6.1 12.0 5.1

Arklow 110 kV 8.3 21.0 8.2 9.2 25.7 10.3 8.5 18.5 7.0 9.4 22.8 9.0

Arklow 220 kV 9.0 19.4 7.8 10.3 18.1 7.6 9.3 16.0 6.3 10.4 15.6 6.4

Arva 110 kV 3.3 19.3 9.0 4.5 15.5 7.1 3.4 17.9 8.0 4.6 14.5 6.5

Athea 110 kV 6.5 21.4 7.8 8.4 17.5 6.9 7.0 19.3 6.7 8.8 16.6 6.4

Athlone 110 kV 4.6 21.9 9.7 5.7 16.0 7.0 4.8 20.5 8.8 5.9 15.3 6.6

Athy 110 kV 3.1 12.5 6.3 4.3 9.9 4.7 3.3 10.9 5.3 4.4 9.0 4.2

Aughinish 110 kV 7.6 24.4 9.7 9.7 26.8 10.7 7.9 22.6 8.8 9.9 25.7 10.2

Balgriffin 110 kV 15.0 39.2 15.2 8.8 40.6 16.6 13.9 30.3 11.7 9.0 33.1 13.4

Balgriffin 220 kV 15.0 40.9 16.9 6.8 44.6 18.8 13.1 26.5 10.7 7.6 30.9 12.9

Ballakelly 220 kV 10.1 51.9 21.0 9.9 49.1 20.5 10.4 40.8 16.1 10.2 38.5 15.9

Ballybeg 110 kV 8.9 15.9 6.4 9.3 18.8 7.6 9.0 14.2 5.6 9.4 17.0 6.8

Ballycummin 110 kV 4.7 28.9 12.8 5.9 25.3 11.0 4.8 24.3 10.5 5.8 22.4 9.7

Ballydine 110 kV 2.9 13.3 6.8 4.2 10.1 4.8 3.0 11.6 5.7 4.2 9.3 4.4

Ballylickey 110 kV 2.8 6.3 3.1 4.1 4.2 2.0 2.9 6.1 3.0 4.1 4.0 1.9

Ballywater 110 kV 4.3 13.0 5.6 3.1 11.9 5.9 4.5 11.7 4.9 3.2 11.0 5.4

Baltrasna 110 kV 6.0 23.8 10.3 7.3 18.9 8.0 6.1 20.9 8.8 7.3 17.2 7.2

Bandon 110 kV 3.1 13.1 6.3 4.5 11.3 5.2 3.3 12.0 5.7 4.6 10.7 4.9

Banoge 110 kV 3.6 12.8 5.9 4.6 11.4 5.2 3.8 11.5 5.1 4.7 10.5 4.7

Barnahely A 110 kV 4.3 28.0 12.4 5.1 29.1 12.9 4.6 22.3 9.7 5.2 24.2 10.7

Barnahely B 110 kV 6.3 29.5 12.1 7.0 29.7 12.4 6.1 23.6 9.6 6.7 24.9 10.5

Baroda 110 kV 3.9 18.2 8.5 4.8 21.3 9.6 4.2 15.4 7.0 5.1 18.6 8.3

Barrymore 110 kV 3.5 16.4 7.9 4.8 10.0 4.6 3.6 13.9 6.5 4.8 9.0 4.1

Bellacorick 110 kV 3.1 8.2 3.9 4.2 8.3 3.9 2.8 6.5 3.1 3.8 7.1 3.4

Binbane 110 kV 3.9 10.5 4.2 5.6 9.6 4.1 3.2 6.6 2.7 4.7 6.8 2.9

Blake 110 kV 3.9 17.0 8.0 5.0 12.1 5.5 4.1 14.6 6.7 5.1 11.0 4.9

Boggeragh 110 kV 15.1 14.2 5.5 12.0 8.8 3.5 7.4 17.9 7.0 7.8 11.2 4.6

Booltiagh 110 kV 3.1 8.6 4.2 4.4 8.0 3.7 3.1 8.1 4.0 4.5 7.9 3.6


E-11

Table E -3 Short C i rcui t Current s for Maxi mum and Mi nimum Demand in 2013 (cont inued)



B u s X/R

R a t i o

P e a k M a k e [ k A ]

Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o

P e a k M a k e [ k A ]

Tot RMS

Break [kA]

Bracklone 110 kV 3.4 13.9 6.8 4.6 9.9 4.6 3.6 12.1 5.7 4.7 9.1 4.2

Brinny A 110 kV 3.0 11.6 5.7 4.3 9.5 4.4 3.1 10.7 5.1 4.4 9.0 4.1

Brinny B 110 kV 3.0 11.7 5.7 4.3 9.5 4.4 3.1 10.7 5.2 4.4 9.1 4.2

Bunbeg 110 kV 3.0 4.3 2.0 4.3 2.8 1.3 - - - - - -

Butlerstown 110 kV 4.4 23.2 10.4 4.6 22.2 10.1 4.3 17.5 7.7 4.6 18.1 8.2

Cahir 110 kV 2.9 15.0 7.6 4.2 9.5 4.5 3.1 13.7 6.7 4.3 9.5 4.4


Carlow 110 kV 5.3 21.2 9.3 6.1 20.8 9.0 5.4 16.2 6.9 6.1 17.1 7.4

Carrickmines A 110 kV 23.1 35.8 14.5 19.8 37.6 15.2 20.9 29.8 11.7 18.8 32.4 12.9


Carrickmines 220 kV 14.7 50.0 20.3 10.5 57.5 23.6 13.8 35.0 13.9 10.9 42.4 17.3


Carrowbeg 110 kV 2.7 5.8 3.0 4.0 5.6 2.6 2.7 5.4 2.7 4.0 5.2 2.4

Cashla 110 kV 6.2 37.1 15.4 7.1 46.2 19.3 6.1 30.1 12.3 6.8 38.3 15.9

Cashla 220 kV 7.7 27.3 11.2 9.8 26.9 11.2 7.6 19.9 8.0 9.3 21.2 8.8

Castlebar 110 kV 3.2 10.4 4.9 4.5 9.8 4.5 3.2 9.2 4.2 4.5 9.0 4.1

Castledockrill 110 kV 7.0 19.9 7.4 4.5 21.6 9.4 7.3 17.6 6.3 4.7 19.4 8.3

Castlefarm A 110 kV 6.9 23.2 9.4 8.5 24.6 10.0 7.2 21.4 8.5 8.7 23.5 9.5

Castlefarm B 110 kV 6.9 23.1 9.4 8.5 24.5 10.0 7.2 21.4 8.5 8.7 23.5 9.5

Castleview 110 kV 3.7 27.9 13.0 4.5 20.6 9.5 4.0 22.1 9.9 4.6 17.5 7.9


Cauteen 110 kV 2.8 12.8 6.5 4.0 7.9 3.7 3.0 11.8 5.8 4.1 7.4 3.5

Mid-Cavan 220 kV 11.1 37.4 15.4 10.3 36.1 15.1 11.5 31.6 12.7 10.7 30.2 12.5

Mid-Cavan 400 kV 14.3 26.8 11.3 10.3 22.7 9.5 14.5 22.2 9.2 10.8 18.9 7.9

Charleville 110 kV 3.7 14.1 6.4 5.1 9.8 4.4 3.8 12.9 5.7 5.1 9.2 4.1

Cherrywood 110 kV 10.3 25.4 10.1 8.5 26.3 10.8 10.5 21.8 8.5 8.7 23.4 9.6

Clahane 110 kV 3.9 23.6 9.8 5.4 19.6 8.4 4.3 21.0 8.1 5.7 18.4 7.7

Clashavoon A 110 kV 5.7 27.9 11.0 7.3 28.1 11.5 7.8 34.0 12.3 9.3 33.8 13.2

Clashavoon B 110 kV 26.1 19.6 8.1 25.4 16.5 6.9 7.8 34.0 12.3 9.3 33.8 13.2

Clashavoon 220 kV 10.0 26.1 10.5 11.3 21.8 9.1 9.9 21.3 8.3 11.0 20.8 8.6

Cliff 110 kV 4.4 18.0 7.2 5.5 15.4 6.6 4.0 14.1 5.7 5.0 13.5 5.8

Clonkeen A 110 kV 6.2 18.8 6.2 6.6 18.8 7.3 6.6 18.7 5.8 6.9 18.9 7.1

Cloon 110 kV 4.4 16.7 7.6 5.5 11.8 5.2 4.5 14.8 6.6 5.5 10.8 4.7

College Park 110 kV 8.5 44.9 18.0 6.6 47.4 20.2 8.3 35.6 14.1 6.8 39.0 16.4

Coolroe 110 kV 3.3 20.6 9.6 4.6 19.7 8.9 3.4 17.5 8.2 4.5 17.7 8.0


Corderry 110 kV 4.6 19.2 7.6 6.0 17.7 7.4 4.8 17.4 6.6 6.2 16.2 6.6


E-12




B u s X/R

R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

Corduff A 110 kV 9.8 52.8 20.8 11.2 58.6 23.4 9.2 40.7 15.8 10.5 46.7 18.5

Corduff B 110 kV 9.8 52.8 20.8 11.2 58.6 23.4 9.2 40.7 15.8 10.5 46.7 18.5

Corduff 220 kV 16.9 65.0 26.8 15.7 73.1 31.0 13.4 36.1 14.4 13.3 43.8 18.2

Corraclassy 110 kV 3.7 13.7 6.2 5.0 11.0 4.9 3.8 13.0 5.7 5.1 10.4 4.6

Cow Cross 110 kV 4.0 27.9 12.6 4.6 23.6 10.7 4.3 22.2 9.8 4.8 20.0 9.0

Crane 110 kV 5.9 20.5 8.1 6.1 21.0 8.8 6.1 18.0 6.8 6.3 19.0 7.8

Cullenagh 110 kV 5.5 29.2 12.4 6.4 33.2 14.1 5.4 22.0 9.2 6.2 26.2 11.1

Cullenagh 220 kV 8.9 20.8 8.4 10.5 19.7 8.2 7.8 15.0 6.0 9.3 15.5 6.4

Cunghill 110 kV 3.1 11.8 5.4 4.5 10.8 4.9 3.1 10.1 4.5 4.3 9.7 4.4

Cushaling 110 kV 7.2 28.7 11.1 9.2 26.4 10.6 6.0 18.4 7.4 7.6 20.1 8.2

Dallow 110 kV 3.4 10.9 5.2 4.6 7.1 3.3 3.5 10.2 4.8 4.7 6.7 3.1

Dalton 110 kV 2.8 8.6 4.3 4.0 6.1 2.9 2.9 7.8 3.8 4.0 5.7 2.7

Derrybrien 110 kV 3.1 9.8 4.3 4.5 9.2 4.1 3.2 9.3 3.9 4.6 9.0 3.9

Derryiron 110 kV 5.9 22.5 9.5 7.6 21.4 8.9 5.3 13.1 5.7 6.6 14.8 6.3

Doon 110 kV 2.8 12.6 6.5 4.0 8.4 4.0 2.9 11.2 5.6 4.1 8.0 3.8

Dromada 110 kV 5.3 17.9 6.9 4.9 14.1 6.2 5.7 16.3 6.0 5.1 13.4 5.7

Drumkeen 110 kV 3.9 15.3 5.8 5.1 13.3 5.6 3.9 13.7 4.9 5.1 12.3 5.0

Drumline 110 kV 3.1 15.9 7.8 4.3 13.6 6.4 3.2 14.0 6.7 4.3 12.4 5.7

Drybridge 110 kV 5.3 30.8 13.4 6.4 26.2 11.3 5.5 27.1 11.4 6.6 23.5 10.0

Dundalk 110 kV 3.5 18.7 8.9 4.6 17.3 7.9 3.6 17.1 7.9 4.7 15.7 7.1

Dunfirth 110 kV 4.6 14.4 6.5 5.9 9.5 4.2 4.8 11.2 5.0 6.0 8.1 3.5

Dungarvan 110 kV 3.6 12.1 5.8 4.7 7.7 3.5 3.8 10.5 4.9 4.8 7.0 3.2

Dunmanway 110 kV 3.9 16.9 7.5 5.5 14.7 6.4 4.3 16.8 7.2 5.8 14.7 6.3

Dunstown 220 kV 11.3 49.2 19.8 10.6 45.0 18.7 12.0 36.6 14.4 11.3 36.0 14.8

Dunstown 400 kV 19.9 15.8 7.0 14.6 12.6 5.4 19.2 12.6 5.5 14.8 10.5 4.5

Ennis 110 kV 3.3 20.1 9.6 4.6 19.0 8.7 3.5 18.1 8.3 4.7 17.6 8.0

Fassaroe A 110 kV 5.1 17.7 7.8 5.5 13.2 5.8 5.3 15.7 6.8 5.6 12.1 5.3

Fassaroe B 110 kV 5.2 18.2 8.0 5.6 13.6 6.0 5.4 16.1 6.9 5.7 12.5 5.5

Finnstown 110 kV 17.4 42.8 16.8 8.2 45.1 18.6 16.5 35.3 13.5 8.6 38.4 15.6

Finnstown 220 kV 12.4 59.9 24.0 10.9 60.1 24.8 12.5 41.1 16.1 11.5 44.3 18.2

Finglas 220 kV 18.4 64.4 26.9 17.1 75.8 32.5 13.8 35.2 14.2 13.8 44.2 18.4

Kildonan 110 kV 6.6 34.2 14.4 5.5 29.1 12.9 6.6 28.3 11.7 5.6 25.3 11.1

Finglas A 110 kV 26.1 44.2 18.2 19.2 48.0 19.3 20.1 33.4 13.1 17.0 38.0 15.1

Finglas B 110 kV 38.1 37.9 16.9 33.0 46.1 20.2 26.4 27.9 11.5 25.1 35.0 14.6

Flagford 110 kV 4.5 27.6 11.9 5.4 33.5 14.5 4.7 24.8 10.2 5.6 30.1 12.8

Flagford 220 kV 7.2 19.2 7.9 9.5 17.9 7.5 7.5 16.8 6.7 9.7 15.9 6.6

Galway 110 kV 4.3 25.4 11.5 5.0 27.1 12.2 4.3 21.5 9.5 5.0 23.7 10.5


E-13




B u s X/R

R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

Garrow A 110 kV 4.6 14.9 5.3 3.6 14.2 6.3 4.7 14.7 5.0 3.6 14.1 6.1

Garvagh 110 kV 5.1 15.2 5.8 6.8 13.8 5.6 5.2 13.9 5.1 6.9 12.7 5.1

Gilra 110 kV 3.0 13.2 6.5 4.0 10.7 5.0 3.1 12.1 5.8 4.0 9.8 4.6

Glanagow 220 kV 17.2 32.8 13.4 17.1 39.0 16.7 12.7 21.7 8.5 13.0 27.3 11.3

Glanlee 110 kV 6.6 15.5 5.0 7.0 16.7 6.3 6.9 15.4 4.7 7.3 16.8 6.2

Glasmore 110 kV 4.4 16.7 7.7 4.9 11.5 5.2 4.7 14.6 6.5 5.0 10.6 4.8

Glenlara A 110 kV 3.7 7.6 3.2 5.6 5.8 2.5 3.8 7.3 3.0 5.7 5.6 2.4

Glenree 110 kV 3.5 10.1 4.6 4.6 8.4 3.8 3.0 7.5 3.5 3.9 7.0 3.2

Golagh 110 kV 3.0 10.0 4.5 4.1 6.6 3.1 3.1 9.1 3.9 4.1 6.2 2.8

Gorman 110 kV 5.8 33.8 14.4 6.9 37.5 15.8 6.1 29.9 12.3 7.2 33.2 13.8

Gorman 220 kV 8.6 30.6 12.6 9.8 24.3 10.2 9.1 25.7 10.3 10.1 21.1 8.8

Gortawee 110 kV 3.9 13.3 6.0 5.5 11.3 5.0 4.0 12.5 5.5 5.6 10.9 4.7

Grange 110 kV 11.7 36.6 14.3 6.5 37.0 15.8 11.5 28.7 11.1 6.9 30.5 12.9

Grange Castle 110 kV 18.0 43.2 17.0 8.7 46.0 18.8 17.0 35.5 13.7 9.0 39.1 15.8

Great Island 110 kV 7.0 35.3 14.0 7.8 44.1 18.0 5.6 22.1 9.1 6.2 29.5 12.4

Great Island 220 kV 10.1 25.2 10.0 11.8 25.7 10.7 7.9 16.6 6.6 9.4 19.0 7.8

Griffinrath 110 kV 6.9 25.8 10.8 7.3 25.8 10.9 7.5 21.6 8.8 7.8 22.3 9.3

Hartnett's Cross 110 kV 3.6 18.4 8.3 4.6 14.3 6.5 4.0 18.7 8.2 4.9 14.2 6.3

Huntstown A 220 kV 17.4 61.9 25.6 14.2 72.0 30.1 13.6 34.5 13.9 12.6 42.9 17.8

Huntstown B 220 kV 15.8 57.8 23.8 11.7 64.4 26.6 12.8 32.8 13.1 11.2 39.5 16.2

Ikerrin 110 kV 4.5 10.3 4.7 6.0 6.9 3.0 4.6 9.6 4.4 6.1 6.6 2.9

Inchicore A 220 kV 14.0 52.4 21.2 8.8 57.7 23.7 13.2 36.3 14.3 9.5 42.5 17.3

Inchicore B 220 kV 14.1 47.3 19.4 12.1 49.8 20.8 13.4 33.6 13.5 12.1 37.4 15.5

Inchicore A 110 kV 31.6 38.2 16.5 27.6 47.3 20.1 26.5 31.7 13.0 24.6 39.8 16.5

Inchicore B 110 kV 29.7 47.4 20.1 23.8 57.9 23.9 24.8 38.5 15.5 21.5 47.8 19.3

Inniscarra 110 kV 3.4 20.0 9.3 4.6 18.5 8.4 3.4 17.1 8.0 4.5 16.8 7.7

Irishtown 220 kV 16.3 54.9 22.5 13.7 64.2 26.7 14.3 36.9 14.6 13.2 45.6 18.8

Keelderry 110 kV 3.4 8.5 3.7 4.9 7.2 3.2 3.4 8.1 3.4 5.0 7.0 3.1

Kellis 110 kV 6.3 23.4 10.0 7.5 26.9 11.3 6.3 17.6 7.4 7.4 21.3 8.9

Kellis 220 kV 8.0 20.0 8.3 10.0 17.0 7.1 7.8 15.5 6.3 9.6 14.2 5.9

Kilbarry 110 kV 5.9 49.4 19.8 6.7 48.5 20.2 5.7 35.3 14.2 6.4 37.8 15.8

Kilkenny 110 kV 4.2 16.7 7.7 6.1 13.3 5.8 3.0 8.6 4.3 4.2 8.8 4.1

Killonan 110 kV 5.5 42.7 18.0 6.5 50.4 21.3 5.5 34.2 14.0 6.4 41.6 17.4

Killonan 220 kV 5.5 23.8 10.2 7.4 23.5 9.9 5.9 19.4 8.0 7.6 20.1 8.4

Killoteran 110 kV 4.8 25.4 11.1 4.7 25.3 11.5 4.6 18.6 8.1 4.6 20.1 9.1

Kilmahud 110 kV 13.4 40.1 15.6 6.7 41.8 17.7 13.3 33.3 12.7 7.1 35.9 15.0


E-14




B u s X/R

R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

Kilmore 110 kV 17.7 41.0 16.1 11.9 43.9 17.5 15.6 31.4 12.1 11.7 35.3 14.0

Kilpaddoge 110 kV 10.9 59.0 21.6 12.5 58.5 22.7 10.1 44.0 15.5 11.6 47.0 17.9

Kilpaddoge 220 kV 16.0 55.2 22.4 15.0 63.0 26.5 11.9 31.5 12.1 12.2 39.6 16.1

Kilteel 110 kV 4.3 16.8 7.7 5.5 15.3 6.8 4.5 14.4 6.5 5.6 13.8 6.1

Kiltoy 110 kV 3.8 14.1 5.6 4.9 11.4 4.9 3.8 12.3 4.6 4.9 10.2 4.3

Kinnegad 110 kV 4.7 18.9 8.5 6.3 16.8 7.2 5.0 10.9 4.8 6.4 10.6 4.6

Knockacummer 110 kV 3.7 7.0 3.0 4.6 5.2 2.3 3.8 6.8 2.8 4.6 5.0 2.2

Knockearagh 110 kV 5.5 15.3 5.8 7.0 13.6 5.5 5.7 14.5 5.2 7.3 13.0 5.2

Knockraha A 110 kV 7.8 58.6 22.7 8.8 56.3 22.7 19.8 14.7 5.8 22.1 15.0 6.2

Knockraha B 110 kV 7.8 58.6 22.7 8.8 56.3 22.7 7.2 39.2 15.2 8.1 40.0 16.2

Knockraha A 220 kV 8.9 32.0 12.7 10.0 33.7 13.9 8.4 21.6 8.5 9.4 24.4 10.0

Knockraha B 220 kV 11.9 24.8 10.0 12.3 24.3 10.1 10.7 18.1 7.2 11.1 18.9 7.8

Knockumber 110 kV 3.5 17.1 8.3 4.4 13.4 6.2 3.6 15.8 7.4 4.5 12.5 5.7

Lanesboro 110 kV 3.8 23.5 10.8 5.1 23.8 10.6 4.0 21.1 9.3 5.3 22.6 9.9

Letterkenny 110 kV 4.4 18.6 6.8 5.5 17.3 7.1 4.2 15.8 5.5 5.3 14.9 6.0



Limerick 110 kV 4.6 35.6 15.6 5.6 34.5 15.1 4.7 28.9 12.3 5.5 29.7 12.9

Lisdrum 110 kV 2.7 10.1 5.2 3.8 6.4 3.1 2.8 9.5 4.7 3.9 6.3 3.0

Lisheen 110 kV 3.6 7.9 3.8 5.2 5.8 2.6 3.7 7.4 3.5 5.2 5.6 2.5

Lodgewood 110 kV 8.6 23.3 8.4 9.1 28.8 11.2 8.8 20.3 7.1 9.3 25.4 9.7

Lodgewood 220 kV 9.2 18.5 7.4 10.7 18.1 7.5 9.0 14.8 5.8 10.4 15.2 6.3

Longpoint 220 kV 12.1 22.7 9.1 14.3 23.8 10.1 12.3 19.2 7.6 14.4 21.3 9.0

Louth 110 kV 9.9 49.8 19.2 10.7 61.5 24.4 10.1 43.2 16.1 10.7 52.0 20.3

Louth 220 kV 10.4 54.2 21.9 11.2 51.4 21.4 10.7 42.6 16.8 11.3 40.1 16.6

Macetown 110 kV 6.9 37.9 15.8 6.9 36.4 15.4 7.0 30.9 12.6 7.0 30.9 13.0

Macroom 110 kV 4.6 26.8 11.2 5.7 24.0 10.3 5.6 28.2 11.1 6.5 25.0 10.4

Mallow 110 kV 3.5 13.8 6.5 5.2 11.7 5.2 3.6 12.4 5.8 5.2 11.0 4.9

Marina 110 kV 6.2 47.3 18.8 6.9 50.5 20.9 5.7 33.1 13.4 6.3 38.4 16.1

Maynooth A 110 kV 11.1 34.9 13.8 11.9 42.4 16.9 11.9 28.2 10.9 12.5 34.8 13.8

Maynooth B 110 kV 8.3 41.7 16.9 10.2 39.3 15.9 8.9 33.7 13.3 10.6 33.3 13.3

Maynooth A 220 kV 10.5 50.2 20.1 10.7 45.2 18.8 11.2 36.8 14.4 11.3 35.7 14.7

Maynooth B 220 kV 10.6 56.4 22.6 10.6 50.7 21.1 11.3 39.8 15.6 11.2 39.0 16.0

Meath Hill 110 kV 3.7 20.3 9.5 5.0 17.0 7.7 3.8 18.6 8.4 5.1 15.9 7.1

Meentycat 110 kV 3.7 12.8 4.9 5.2 11.3 4.8 3.8 11.8 4.2 5.2 10.8 4.4

Midleton 110 kV 3.4 22.8 10.9 4.6 18.6 8.5 3.7 18.6 8.6 4.7 16.1 7.3


E-15




B u s X/R

R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

Moneypoint G1 400 kV 25.4 28.3 12.8 22.6 29.4 13.4 18.3 19.0 8.0 18.5 21.7 9.4

Moneypoint G2 400 kV 33.6 11.0 5.3 25.1 11.3 5.2 18.9 6.1 2.6 18.3 7.3 3.2

Moneypoint G3 400 kV 25.4 28.3 12.8 22.6 29.4 13.4 18.3 19.0 8.0 18.5 21.7 9.4

Moneypoint 110 kV 2.7 4.7 2.5 3.9 3.4 1.6 2.7 4.5 2.3 3.9 3.3 1.6

Moneypoint A 220 kV 13.2 30.1 12.2 10.3 27.0 11.2 10.3 18.5 7.3 9.4 19.5 8.0

Moneypoint B 220 kV 16.3 51.2 21.0 12.8 58.0 24.0 12.5 30.6 11.8 11.4 38.0 15.4

Moneteen 110 kV 5.0 24.7 10.8 6.1 19.5 8.4 5.1 21.3 9.1 6.1 17.6 7.6

Monread 110 kV 4.0 16.2 7.6 5.0 15.5 7.0 4.3 13.9 6.3 5.1 14.0 6.3

Moy 110 kV 4.0 10.4 4.6 5.2 11.3 5.0 2.9 6.7 3.2 3.6 8.1 3.8

Mullagharlin 110 kV 3.6 19.6 9.3 4.6 18.1 8.3 3.7 17.9 8.3 4.7 15.7 7.1

Mullingar 110 kV 3.5 14.8 7.2 4.9 14.6 6.6 2.8 7.7 4.0 3.8 8.7 4.2

Mulreavy 110 kV 7.4 12.5 4.8 7.4 6.3 2.6 7.1 11.1 4.2 7.3 5.8 2.4

Mungret A 110 kV 4.7 23.1 10.3 5.8 17.9 7.8 4.8 20.1 8.7 5.9 16.3 7.1

Mungret B 110 kV 4.7 23.2 10.3 5.8 17.9 7.8 4.8 20.1 8.7 5.8 16.3 7.1

Nangor 110 kV 14.8 41.2 16.1 7.0 42.9 18.1 14.4 34.1 13.0 7.3 36.7 15.2

Navan 110 kV 4.9 28.5 12.6 5.9 28.3 12.3 5.2 25.6 10.9 6.1 25.6 11.0

Nenagh 110 kV 2.6 7.1 3.7 3.8 4.4 2.1 2.7 6.5 3.3 3.9 4.1 2.0

Newbridge 110 kV 4.1 21.6 9.9 5.0 21.1 9.5 4.4 17.7 7.9 5.2 18.3 8.1

Nore 110 kV 4.3 16.4 7.6 5.4 12.7 5.6 2.9 8.3 4.2 3.8 8.3 4.0

North Wall 220 kV 16.8 58.6 24.1 9.5 61.7 25.2 13.0 32.4 13.0 9.8 38.1 15.6

Oldcourt A 110 kV 3.6 22.6 10.6 4.3 17.6 8.2 3.8 18.5 8.5 4.5 15.3 7.0

Oldcourt B 110 kV 3.6 22.8 10.7 4.4 17.9 8.3 3.9 18.7 8.5 4.5 15.5 7.1

Oldstreet 220 kV 15.6 29.2 12.2 13.0 30.2 12.7 12.9 19.0 7.8 11.8 21.6 9.0

Oldstreet 400 kV 16.1 22.9 9.7 11.0 19.7 8.3 13.8 16.7 6.8 10.9 15.8 6.6

Oughtragh 110 kV 3.5 10.7 4.9 4.7 7.0 3.2 3.6 9.9 4.4 4.8 6.6 2.9

Platin 110 kV 4.7 27.4 12.3 5.5 21.1 9.3 4.9 24.2 10.6 5.7 19.2 8.4

Pollaphuca 110 kV 3.3 6.2 3.1 4.7 5.5 2.5 2.8 4.5 2.3 4.0 4.6 2.2

Poolbeg A 110 kV 26.1 32.7 13.7 21.9 40.1 16.4 23.1 27.6 11.1 20.3 34.2 13.8

Poolbeg B 110 kV 26.1 32.7 13.6 21.9 40.0 16.4 23.0 27.6 11.1 20.3 34.2 13.8

Poolbeg A 220 kV 17.3 58.6 24.3 10.5 65.0 26.6 13.4 32.6 13.1 10.5 39.6 16.2

Poolbeg B 220 kV 14.7 46.2 19.1 13.1 50.2 21.1 13.6 32.8 13.2 12.8 37.5 15.6

Portlaoise 110 kV 3.8 18.4 8.6 5.4 15.5 6.9 4.1 15.7 7.1 5.5 13.9 6.1

Prospect 220 kV 11.9 40.4 16.1 10.2 36.4 15.1 9.8 24.2 9.4 9.4 25.6 10.5

Raffeen 220 kV 15.5 32.4 13.1 13.3 37.7 15.6 11.9 21.6 8.5 11.1 26.7 10.9

Raffeen A 110 kV 5.2 34.1 14.4 6.0 40.1 17.2 5.4 26.3 11.0 6.0 32.0 13.6

Raffeen B 110 kV 7.8 35.8 14.0 8.7 41.6 16.7 7.2 27.7 10.9 8.0 33.4 13.5


E-16




B u s X/R

R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

X/R R a t i o


Tot RMS

Break [kA]

Ralappane 110 kV 8.9 46.5 17.6 9.6 40.0 16.0 8.7 36.3 13.2 9.4 33.6 13.2

Rathkeale 110 kV 3.4 16.1 7.7 4.6 9.8 4.5 3.5 14.0 6.5 4.6 8.9 4.1

Ratrussan 110 kV 3.4 15.7 6.8 4.5 17.3 7.7 3.5 14.8 6.1 4.6 16.9 7.3

Richmond A 110 kV 2.9 10.8 5.4 4.0 7.7 3.6 3.0 9.9 4.9 4.1 7.2 3.4

Richmond B 110 kV 2.9 10.7 5.4 4.2 10.1 4.7 3.0 9.8 4.8 4.3 9.5 4.4

Rinawade 110 kV 4.9 24.2 10.8 6.0 17.3 7.5 5.2 20.3 8.8 6.2 15.3 6.6

Ringaskiddy 110 kV 5.5 27.8 11.7 6.0 26.7 11.5 5.5 22.4 9.4 5.9 22.6 9.7

Ryebrook 110 kV 5.3 29.8 13.1 6.0 20.7 9.0 5.5 24.9 10.6 6.1 18.4 7.9

Salthill 110 kV 3.8 22.0 10.3 3.7 22.3 10.7 3.9 18.9 8.6 3.8 19.7 9.4

Screeb 110 kV 3.3 4.9 2.5 4.3 3.1 1.4 3.3 4.6 2.2 4.3 2.9 1.3

Sealrock 110 kV 7.4 23.9 9.6 9.1 26.2 10.6 7.6 22.1 8.6 9.4 25.2 10.0

Sealrock 110 kV 7.4 23.9 9.6 9.1 26.2 10.6 7.6 22.1 8.6 9.4 25.2 10.0

Shankill 110 kV 3.3 17.8 8.1 4.5 16.4 7.4 3.4 16.6 7.2 4.6 15.5 6.9



Shellybanks A 220 kV 16.9 58.4 24.1 10.4 65.0 26.6 13.3 32.5 13.1 10.5 39.5 16.2

Shellybanks B 220 kV 15.6 53.4 21.7 12.7 62.2 25.7 13.6 35.7 14.1 12.3 44.1 18.0

Singland 110 kV 5.5 35.4 15.0 6.5 34.3 14.6 5.3 28.2 11.7 6.2 29.0 12.3

Sligo 110 kV 3.6 20.2 8.9 4.7 19.2 8.6 3.7 17.8 7.4 4.7 17.4 7.6

Somerset 110 kV 2.9 15.6 7.7 4.0 10.8 5.1 3.0 14.5 7.0 4.1 10.1 4.7

Sorne Hill 110 kV 3.3 6.3 2.6 3.9 7.5 3.4 3.3 5.9 2.3 3.9 7.2 3.1

Srananagh 110 kV 4.5 25.3 10.3 5.7 27.5 11.6 4.7 22.1 8.6 5.9 24.5 10.1

Srananagh 220 kV 7.1 11.8 4.8 9.7 9.6 4.0 7.2 10.5 4.2 9.8 8.8 3.6

Stevenstown 110 kV 4.2 13.4 6.3 4.7 8.9 4.1 4.4 12.0 5.5 4.9 8.3 3.8

Stratford 110 kV 3.3 9.1 4.5 4.4 7.1 3.3 3.2 7.2 3.5 4.2 6.1 2.9

Tynagh 110 kV 6.5 23.4 9.9 2.3 19.4 10.5 6.7 20.4 8.5 2.5 17.6 9.4

Tarbert 110 kV 15.9 50.2 18.5 18.9 47.2 18.7 11.7 32.5 11.8 14.2 35.5 13.7

Tarbert 220 kV 16.4 55.2 22.4 16.3 63.3 26.8 11.5 30.4 11.7 12.2 38.7 15.7

Tawnaghmore 110 kV 3.8 8.5 3.9 5.1 8.6 3.8 2.7 5.5 2.7 3.6 6.3 3.0

Tawnaghmore 110 kV 3.9 8.7 3.9 5.2 9.0 4.0 2.7 5.5 2.7 3.6 6.4 3.1

Thornsberry 110 kV 4.4 15.3 6.9 5.8 14.0 6.1 4.8 11.3 5.0 6.0 11.3 4.9

Thurles 110 kV 3.9 10.2 4.8 6.0 8.7 3.8 4.0 9.5 4.4 6.1 8.6 3.7

Tievebrack 110 kV 4.5 9.7 3.9 6.0 7.4 3.1 - - - - - -

Tipperary 110 kV 2.7 11.3 5.9 3.9 6.9 3.3 2.8 10.4 5.3 4.0 6.6 3.1

Tonroe 110 kV 2.7 6.7 3.4 3.9 4.4 2.1 2.8 6.3 3.1 3.9 4.1 2.0

Trabeg 110 kV 5.8 45.8 18.5 6.0 48.1 20.4 5.6 32.6 13.2 5.7 37.2 15.9


E-17

Table E -3 Short C i rcui t Current s for Maxi mum and Minimum Demand in 2013 (cont inued)



Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Tralee 110 kV 4.1 24.6 10.1 5.5 19.9 8.5 4.6 22.0 8.5 5.8 18.6 7.8

Trien A 110 kV 5.5 34.1 12.9 7.0 28.2 11.5 6.2 28.9 10.2 7.4 25.6 10.1

Trillick 110 kV 3.3 6.9 2.8 4.0 7.4 3.3 3.4 6.4 2.5 4.1 7.1 3.1

Tullabrack 110 kV 2.7 5.1 2.6 3.9 3.8 1.8 2.7 4.8 2.5 4.0 3.6 1.7

Turlough Hill 220 kV 11.2 32.0 12.9 12.5 27.8 11.7 11.5 25.6 10.1 12.7 23.7 9.9

Tynagh 220 kV 15.0 32.1 13.2 17.1 34.8 15.0 10.2 17.6 7.1 11.5 21.8 9.1

Waterford 110 kV 5.6 28.9 12.2 6.0 28.9 12.5 5.0 20.3 8.6 5.5 22.2 9.7

Wexford 110 kV 3.9 14.7 6.3 5.2 13.4 5.9 4.1 12.9 5.3 5.3 12.3 5.3

Whitegate 110 kV 4.2 22.2 10.0 5.1 23.0 10.3 4.4 17.9 8.0 5.1 19.4 8.6

Woodland 220 kV 12.9 61.0 24.7 11.9 56.7 23.6 13.1 40.0 16.0 12.3 40.6 16.9

Woodland 400 kV 17.3 28.2 12.2 14.2 25.8 11.0 16.4 22.0 9.2 14.2 20.5 8.7

Tabl e E -4 Shor t C i r c ui t Cur r ent s f or Maximum and Minimum Demand in 20 16



Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Adamstown 110 kV 13.8 40.5 15.8 6.6 41.7 17.8 13.2 33.4 12.8 6.9 36.0 15.1

Agannygal 110 kV 3.0 12.2 5.6 4.3 10.1 4.6 3.1 11.4 5.0 4.3 9.6 4.3

Aghada 110 kV 4.6 20.6 9.2 5.6 24.4 10.7 4.8 16.8 7.4 5.7 20.5 8.9

Aghada A 220 kV 10.4 19.8 7.9 12.3 20.8 8.7 7.8 12.1 4.9 9.1 14.4 6.0

Aghada B 220 kV 17.1 32.1 13.2 16.0 37.9 16.0 13.0 20.7 8.2 12.8 26.1 10.8

Aghada C 220 kV 17.1 32.1 13.2 16.0 37.9 16.0 13.0 20.7 8.2 12.8 26.1 10.8

Aghada D 220 kV 11.9 22.4 9.0 13.8 23.4 9.9 11.9 19.1 7.5 13.6 21.1 8.8

Ahane 110 kV 4.5 29.3 13.1 5.3 24.9 11.0 4.6 24.5 10.7 5.3 21.9 9.6

Anner 110 kV 2.7 11.6 6.0 4.0 7.6 3.6 2.8 10.4 5.3 4.0 7.3 3.4

Ardnacrusha 110 kV 5.5 39.2 16.5 6.7 41.8 17.6 5.1 29.9 12.5 6.1 34.3 14.5

Arigna 110 kV 4.8 17.3 7.2 6.0 13.2 5.6 4.9 15.6 6.3 6.0 12.1 5.1

Arklow 110 kV 8.3 21.0 8.2 9.1 25.7 10.3 8.5 18.6 7.0 9.3 23.0 9.1

Arklow 220 kV 9.0 19.4 7.8 10.2 18.1 7.6 9.2 16.1 6.3 10.4 15.8 6.5

Arva 110 kV 3.2 19.3 9.0 4.5 15.4 7.0 3.4 18.2 8.2 4.6 14.7 6.6

Athea 110 kV 15.8 19.4 6.8 16.1 16.3 6.3 15.9 18.1 6.1 16.2 15.9 6.0

Athlone 110 kV 4.6 22.1 9.8 5.7 16.1 7.0 4.8 20.6 8.9 5.9 15.4 6.7

Athy 110 kV 3.2 14.6 7.3 4.3 11.7 5.5 3.4 12.9 6.2 4.4 10.7 5.0


E-18

Table E -4 Short C i rcui t Current s for Maxi mu m and Minimum Demand in 2016 (cont inued)



Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Aughinish 110 kV 7.8 24.1 9.6 9.8 26.2 10.5 8.0 22.6 8.8 10.1 25.7 10.2

Balgriffin 110 kV 15.0 39.2 15.2 8.8 40.6 16.6 12.6 28.4 11.0 8.8 31.8 13.0

Balgriffin 220 kV 15.0 41.0 16.9 6.8 44.7 18.9 11.4 23.1 9.4 7.4 28.0 11.8

Ballakelly 220 kV 10.1 51.3 20.8 10.0 48.5 20.2 11.1 43.5 17.2 10.7 40.9 16.9

Ballybeg 110 kV 8.9 15.9 6.4 9.3 18.8 7.6 9.0 14.4 5.6 9.4 17.3 6.9

Ballycummin 110 kV 4.7 29.2 12.9 5.9 25.4 11.0 4.8 24.6 10.6 5.9 22.6 9.8

Ballydine 110 kV 2.9 13.4 6.8 4.2 10.1 4.8 3.0 11.8 5.8 4.2 9.4 4.4

Ballylickey 110 kV 2.8 6.2 3.1 4.1 4.1 1.9 2.9 5.8 2.8 4.1 3.9 1.8

Ballyragget 110 kV 5.4 16.9 7.5 6.5 11.8 5.1 4.9 13.1 5.8 6.0 10.1 4.4

Ballyvouskill 110 kV 15.6 20.0 6.3 12.1 20.4 7.4 15.2 18.8 5.7 12.0 19.4 6.9

Ballyvouskill 220 kV 9.7 22.3 8.6 10.4 21.8 8.9 10.2 19.0 7.1 10.7 19.3 7.8

Ballywater 110 kV 4.3 13.0 5.6 3.1 11.9 5.9 4.5 11.8 4.9 3.2 11.1 5.4

Baltrasna 110 kV 6.0 23.8 10.2 7.3 19.0 8.0 6.1 21.0 8.9 7.2 17.5 7.3

Bandon 110 kV 3.1 12.9 6.3 4.5 11.2 5.1 3.4 11.5 5.4 4.6 10.4 4.7

Banoge 110 kV 3.6 12.8 5.9 4.6 11.4 5.2 3.8 11.6 5.2 4.7 10.6 4.8

Barnahely A 110 kV 4.4 27.7 12.3 5.2 28.9 12.8 4.8 22.0 9.5 5.4 24.1 10.5

Barnahely B 110 kV 6.4 29.2 12.0 7.1 29.5 12.3 6.5 23.1 9.3 7.1 24.6 10.2

Baroda 110 kV 3.9 18.7 8.8 4.8 21.7 9.9 4.1 16.2 7.4 5.0 19.4 8.7

Barrymore 110 kV 3.5 16.3 7.9 4.8 9.9 4.5 3.7 13.9 6.5 4.8 9.0 4.1

Bellacorick 110 kV 3.1 8.7 4.1 4.2 8.7 4.0 2.8 6.5 3.1 3.7 7.1 3.4

Binbane 110 kV 3.9 10.5 4.2 5.6 9.6 4.1 4.0 9.7 3.7 5.6 9.2 3.8

Blake 110 kV 3.8 17.2 8.2 5.0 12.2 5.5 4.0 15.2 7.0 5.1 11.3 5.1

Boggeragh 110 kV 15.0 13.9 5.3 11.9 8.8 3.5 15.2 13.1 4.9 12.0 8.4 3.3

Booltiagh 110 kV 6.0 18.0 7.7 7.6 15.1 6.3 6.1 16.3 6.8 7.7 14.3 5.9

Bracklone 110 kV 3.3 15.5 7.6 4.4 10.8 5.0 3.5 13.8 6.6 4.5 10.1 4.6

Brinny A 110 kV 3.0 11.4 5.6 4.3 9.4 4.4 3.2 10.3 4.9 4.5 8.8 4.0

Brinny B 110 kV 3.0 11.5 5.7 4.3 9.5 4.4 3.2 10.3 4.9 4.5 8.8 4.1

Bunbeg 110 kV 3.0 4.3 2.0 4.3 2.8 1.3 3.0 4.0 1.9 4.3 2.7 1.2

Butlerstown 110 kV 4.3 23.3 10.4 4.6 22.3 10.2 4.3 17.9 7.9 4.6 18.5 8.4

Cahir 110 kV 3.0 15.3 7.7 4.3 9.5 4.5 3.1 14.1 6.9 4.4 9.6 4.5


Carlow 110 kV 5.2 21.7 9.6 5.9 21.2 9.3 5.3 17.4 7.5 6.0 18.1 7.8

Carrickmines A 110 kV 23.2 35.8 14.5 19.8 37.7 15.2 20.2 29.9 11.7 18.4 32.7 13.0


Carrickmines 220 kV 14.8 50.2 20.4 10.5 57.7 23.7 13.2 34.2 13.5 10.7 41.8 17.0


Carrowbeg 110 kV 2.8 6.7 3.4 4.1 6.1 2.9 2.7 5.4 2.7 4.0 5.2 2.5


E-19




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Cashla 110 kV 6.0 37.4 15.7 6.9 46.6 19.6 6.0 30.2 12.4 6.7 38.5 16.0

Cashla 220 kV 7.6 27.4 11.2 9.7 26.9 11.2 7.5 20.0 8.1 9.3 21.3 8.8

Castlebar 110 kV 3.5 13.4 6.2 4.7 12.3 5.5 3.2 9.3 4.3 4.5 9.0 4.1

Castledockrill 110 kV 7.0 20.0 7.4 4.5 21.6 9.4 7.2 17.7 6.4 4.7 19.5 8.3

Castlefarm A 110 kV 7.0 22.9 9.3 8.6 24.1 9.8 7.3 21.4 8.5 8.8 23.5 9.5

Castlefarm B 110 kV 7.0 22.8 9.2 8.6 24.0 9.8 7.3 21.4 8.4 8.8 23.5 9.4

Castleview 110 kV 3.7 27.7 12.9 4.5 20.5 9.4 4.1 22.0 9.8 4.7 17.4 7.9


Cauteen 110 kV 3.1 14.5 7.2 4.3 8.3 3.9 3.3 13.7 6.6 4.3 7.9 3.7

Mid-Cavan 220 kV 11.1 37.2 15.3 10.3 35.9 15.0 11.6 32.4 13.1 10.8 31.1 12.9

Mid-Cavan 400 kV 14.3 26.6 11.2 10.4 22.6 9.5 14.4 22.2 9.1 10.8 19.0 7.9

Charleville 110 kV 3.5 12.9 6.0 4.8 9.5 4.3 3.7 12.0 5.3 5.0 8.9 4.0

Cherrywood 110 kV 10.3 25.4 10.1 8.5 26.4 10.9 10.4 22.0 8.6 8.6 23.7 9.7

Clahane 110 kV 4.2 19.1 7.9 5.8 16.5 7.0 4.4 16.6 6.5 5.9 15.3 6.4

Clashavoon A 110 kV 5.5 25.5 10.6 7.2 26.1 10.9 6.0 21.9 8.8 7.5 23.1 9.5

Clashavoon B 110 kV 24.5 18.9 7.6 24.9 16.5 6.9 23.4 17.3 6.9 24.4 15.3 6.3

Clashavoon 220 kV 9.7 23.3 9.1 10.9 21.4 8.9 10.0 19.4 7.4 11.1 18.7 7.7

Cliff 110 kV 4.4 18.0 7.3 5.5 15.4 6.6 4.0 14.4 5.8 5.1 13.7 5.9

Clonkeen A 110 kV 5.3 13.2 5.7 6.7 9.8 4.2 5.5 11.9 5.0 6.8 9.1 3.8

Clonkeen B 110 kV 8.6 16.0 4.9 5.3 15.9 6.3 8.7 15.3 4.4 5.4 15.4 5.9

Cloon 110 kV 4.3 17.0 7.8 5.4 11.9 5.3 4.4 14.9 6.6 5.5 10.8 4.8

College Park 110 kV 8.5 44.9 18.0 6.6 47.4 20.2 7.9 34.3 13.7 6.6 38.3 16.2

Coolroe 110 kV 3.4 20.1 9.5 4.6 19.4 8.8 3.5 16.3 7.6 4.6 16.9 7.6


Cordal 110 kV 14.4 15.6 5.9 17.1 16.1 6.4 15.1 14.2 5.3 17.6 15.1 6.0

Corderry 110 kV 4.6 19.4 7.7 6.1 17.8 7.4 4.7 17.6 6.7 6.2 16.4 6.7

Corduff A 110 kV 9.8 52.8 20.8 11.2 58.6 23.4 8.6 38.9 15.3 9.8 45.5 18.2

Corduff B 110 kV 9.8 52.8 20.8 11.2 58.6 23.4 8.6 38.9 15.3 9.8 45.5 18.2

Corduff 220 kV 16.9 65.2 26.9 15.7 73.3 31.1 11.4 30.4 12.2 11.7 38.4 15.9

Corraclassy 110 kV 3.7 13.8 6.3 5.0 11.0 4.9 3.8 13.1 5.7 5.1 10.5 4.7

Cow Cross 110 kV 4.0 27.7 12.5 4.7 23.5 10.7 4.5 22.0 9.6 4.9 19.9 8.9

Crane 110 kV 5.8 20.6 8.1 6.1 21.1 8.9 6.1 18.2 6.9 6.3 19.2 7.9

Cullenagh 110 kV 5.4 29.2 12.5 6.4 33.2 14.2 5.4 22.5 9.4 6.2 26.8 11.4

Cullenagh 220 kV 8.8 20.8 8.4 10.4 19.7 8.2 7.9 15.3 6.2 9.4 15.8 6.5

Cunghill 110 kV 3.1 11.7 5.4 4.5 10.7 4.8 3.1 10.1 4.5 4.3 9.8 4.4

Cushaling 110 kV 7.0 30.0 11.7 9.0 27.2 10.9 5.7 20.1 8.2 7.3 21.7 8.9

Dallow 110 kV 3.4 11.1 5.3 4.6 7.2 3.3 3.5 10.4 4.9 4.7 6.8 3.1


E-20




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Dalton 110 kV 2.8 9.3 4.7 3.9 6.3 3.0 2.9 7.8 3.9 4.0 5.7 2.7

Derrybrien 110 kV 3.1 10.0 4.4 4.5 9.3 4.1 3.2 9.4 4.0 4.6 9.1 4.0

Derryiron 110 kV 5.8 22.5 9.5 7.5 21.4 8.9 4.9 15.8 7.0 6.2 17.1 7.4

Doon 110 kV 2.8 12.7 6.5 4.0 8.4 4.0 2.9 11.4 5.7 4.1 8.0 3.8

Dromada 110 kV 9.9 16.7 5.9 6.9 13.4 5.5 10.0 15.5 5.4 7.0 13.0 5.3

Drumkeen 110 kV 3.9 15.4 5.8 5.1 13.3 5.6 4.0 14.4 5.1 5.2 12.8 5.2

Drumline 110 kV 3.1 17.2 8.5 4.3 14.3 6.7 3.2 15.1 7.3 4.4 13.0 6.0

Drybridge 110 kV 5.3 30.8 13.4 6.4 26.2 11.2 5.5 27.3 11.6 6.5 24.0 10.2

Dundalk 110 kV 3.5 18.6 8.9 4.6 17.3 7.9 3.6 17.6 8.2 4.7 16.1 7.3

Dunfirth 110 kV 4.6 14.4 6.5 5.9 9.5 4.2 4.7 12.7 5.7 5.9 8.8 3.9

Dungarvan 110 kV 3.6 12.1 5.8 4.7 7.7 3.5 3.8 10.6 5.0 4.8 7.1 3.2

Dunmanway 110 kV 3.9 16.3 7.3 5.5 14.5 6.4 4.3 14.6 6.3 5.7 13.4 5.8

Dunstown 220 kV 11.4 49.6 20.0 10.9 46.7 19.4 11.9 36.0 14.2 11.4 36.8 15.2

Dunstown 400 kV 17.1 17.1 7.4 13.0 15.4 6.5 16.4 13.4 5.6 13.1 12.8 5.4

Ennis 110 kV 3.6 24.3 11.4 5.0 21.8 9.8 3.8 21.4 9.7 5.1 20.1 8.9

Fassaroe A 110 kV 5.1 17.7 7.9 5.5 13.1 5.8 5.3 15.9 6.9 5.6 12.3 5.4

Fassaroe B 110 kV 5.2 18.2 8.0 5.6 13.6 6.0 5.4 16.3 7.0 5.7 12.7 5.5

Finnstown 110 kV 17.4 42.8 16.8 8.2 45.1 18.6 15.9 35.1 13.4 8.5 38.5 15.7

Finnstown 220 kV 12.4 60.1 24.1 10.9 60.2 24.9 11.9 39.4 15.4 11.1 43.3 17.7

Finglas 220 kV 18.4 64.6 27.0 17.1 76.0 32.6 11.4 29.2 11.7 11.7 38.0 15.8

Kildonan 110 kV 6.5 34.2 14.4 5.5 29.1 12.9 6.4 27.6 11.5 5.5 25.2 11.1

Finglas A 110 kV 26.1 44.3 18.3 19.2 48.1 19.4 16.9 31.0 12.1 15.3 36.3 14.4

Finglas B 110 kV 38.2 38.0 16.9 33.1 46.1 20.2 21.5 26.4 10.6 21.4 33.7 13.7

Flagford 110 kV 4.5 29.4 12.6 5.4 35.4 15.3 4.6 25.1 10.4 5.6 30.5 13.0

Flagford 220 kV 7.4 19.4 8.0 9.7 18.0 7.5 7.5 17.0 6.8 9.7 16.1 6.7

Galway 110 kV 4.2 25.5 11.7 4.9 27.3 12.3 4.3 21.6 9.6 5.0 23.8 10.6

Garrow A 110 kV 14.1 19.1 5.9 10.4 19.6 7.1 13.9 18.0 5.3 10.4 18.8 6.7

Garrow B 110 kV 14.1 19.1 5.9 10.4 19.6 7.1 13.9 18.0 5.3 10.4 18.8 6.7

Garvagh 110 kV 5.1 15.3 5.8 6.8 13.8 5.6 5.2 14.0 5.2 6.9 12.8 5.1

Gilra 110 kV 3.0 13.6 6.7 4.0 10.9 5.1 3.1 12.2 5.8 4.0 9.9 4.7

Glanagow 220 kV 17.4 32.5 13.4 17.3 38.6 16.6 13.6 21.4 8.5 13.8 27.0 11.2

Glanlee 110 kV 8.6 13.8 4.1 7.3 15.1 5.5 8.7 13.3 3.7 7.4 14.8 5.2

Glasmore 110 kV 4.4 16.7 7.7 4.9 11.5 5.2 4.7 14.3 6.4 5.1 10.7 4.8

Glenlara A 110 kV 3.0 5.9 2.7 4.5 5.2 2.3 3.1 5.8 2.5 4.7 5.1 2.3

Glenlara B 110 kV 13.2 14.1 5.4 10.8 9.5 3.8 12.3 12.0 4.5 10.6 8.7 3.5

Glenree 110 kV 3.5 10.1 4.6 4.6 8.4 3.8 3.0 7.5 3.5 3.9 7.0 3.3

Golagh 110 kV 3.0 10.0 4.5 4.1 6.6 3.1 3.1 9.1 3.9 4.1 6.2 2.8


E-21




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Gorman 110 kV 5.8 33.7 14.4 6.9 37.4 15.8 6.1 30.4 12.5 7.2 33.9 14.1

Gorman 220 kV 8.6 30.5 12.6 9.8 24.3 10.2 9.1 26.2 10.5 10.2 21.6 9.0

Gortawee 110 kV 3.9 13.4 6.1 5.5 11.3 5.0 4.0 12.6 5.6 5.6 11.0 4.8

Grange 110 kV 11.7 36.6 14.3 6.5 37.0 15.8 10.8 27.0 10.6 6.9 29.5 12.5

Grange Castle 110 kV 18.0 43.2 17.0 8.7 46.0 18.8 16.3 35.3 13.6 8.9 39.2 15.8

Great Island 110 kV 6.8 35.6 14.2 7.6 44.4 18.2 5.6 23.2 9.5 6.1 30.7 12.9

Great Island 220 kV 10.0 25.2 10.1 11.7 25.7 10.7 8.1 17.0 6.8 9.6 19.4 8.0

Griffinrath 110 kV 6.8 25.8 10.8 7.3 25.8 10.9 7.1 22.1 9.1 7.5 22.9 9.5

Hartnett's Cross 110 kV 3.6 17.6 8.2 4.6 13.9 6.3 3.9 15.3 6.9 4.8 12.6 5.7

Huntstown A 220 kV 17.4 62.1 25.7 14.2 72.2 30.2 11.1 28.4 11.4 10.9 36.8 15.2

Huntstown B 220 kV 15.8 58.0 23.8 11.7 64.5 26.6 11.2 28.1 11.3 10.2 35.2 14.5

Ikerrin 110 kV 4.5 10.4 4.8 6.0 6.9 3.0 4.6 9.6 4.4 6.1 6.6 2.9

Inchicore A 220 kV 14.0 52.6 21.3 8.8 57.8 23.8 12.7 35.3 13.9 9.4 41.8 17.0

Inchicore B 220 kV 14.2 47.5 19.5 12.1 49.9 20.8 12.5 32.0 12.8 11.6 36.4 15.0

Inchicore A 110 kV 31.6 38.3 16.5 27.7 47.4 20.1 24.8 31.6 12.8 23.4 39.9 16.4

Inchicore B 110 kV 29.8 47.4 20.1 23.8 58.0 24.0 23.1 38.1 15.2 20.5 47.7 19.2

Inniscarra 110 kV 3.4 19.5 9.2 4.6 18.3 8.3 3.5 15.8 7.3 4.5 15.9 7.2

Irishtown 220 kV 16.3 55.1 22.6 13.7 64.4 26.8 13.7 36.0 14.2 12.8 44.9 18.4

Keelderry 110 kV 3.3 8.7 3.8 4.9 7.3 3.2 3.4 8.2 3.5 5.0 7.1 3.1

Kellis 110 kV 6.0 24.0 10.3 7.2 27.4 11.6 6.2 19.1 8.0 7.3 22.7 9.5

Kellis 220 kV 8.0 20.1 8.3 9.9 17.1 7.2 7.9 15.9 6.5 9.7 14.6 6.1

Kilbarry 110 kV 6.0 48.4 19.5 6.8 47.9 20.0 6.1 33.8 13.5 6.7 36.7 15.3

Kilkenny 110 kV 4.8 21.9 9.9 6.5 16.9 7.3 3.8 13.2 6.2 5.1 12.5 5.6

Killonan 110 kV 5.5 44.7 18.8 6.6 52.7 22.2 5.5 35.4 14.5 6.4 43.2 18.1

Killonan 220 kV 5.5 24.2 10.4 7.5 23.8 10.1 5.8 19.8 8.2 7.6 20.4 8.5

Killoteran 110 kV 4.7 25.5 11.2 4.7 25.4 11.5 4.6 19.1 8.3 4.6 20.5 9.3

Kilmahud 110 kV 13.5 40.2 15.7 6.7 41.8 17.8 13.0 33.2 12.7 7.0 36.0 15.0

Kilmore 110 kV 17.7 41.1 16.1 11.9 44.0 17.5 13.9 29.3 11.4 11.1 33.8 13.5

Kilpaddoge 110 kV 12.9 57.6 21.0 14.4 57.9 22.5 11.4 42.9 15.2 12.9 46.3 17.7

Kilpaddoge 220 kV 15.6 57.3 23.2 14.5 66.1 27.7 11.8 32.3 12.5 12.0 41.1 16.7

Kilteel 110 kV 4.3 16.9 7.8 5.4 15.3 6.8 4.4 14.8 6.7 5.5 14.2 6.3

Kiltoy 110 kV 3.8 14.1 5.6 4.9 11.4 4.9 3.9 13.2 4.9 5.0 10.9 4.6

Kinnegad 110 kV 4.7 18.9 8.5 6.3 16.7 7.2 4.5 15.3 6.9 6.0 14.6 6.3

Kishkeam 110 kV 24.2 20.4 8.1 22.7 19.4 7.9 24.0 17.9 7.1 22.7 17.7 7.2

Kishkeam 220 kV 9.8 22.1 8.7 10.8 20.8 8.6 10.3 18.7 7.1 11.1 18.3 7.5

Knockacummer 110 kV 8.5 11.8 4.6 6.0 7.9 3.4 8.6 10.3 4.0 6.1 7.3 3.1


E-22




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Knockanure A 110 kV 27.6 25.8 10.2 23.0 22.2 9.0 25.3 23.3 8.8 22.2 20.7 8.2

Knockanure B 110 kV 4.8 22.0 9.0 6.1 17.1 7.2 5.1 19.1 7.5 6.3 15.6 6.5

Knockanure 220 kV 10.9 33.0 13.1 10.7 27.7 11.5 11.1 24.4 9.5 10.9 22.7 9.3

Knockearagh 110 kV 5.4 13.1 5.5 7.4 11.4 4.7 5.4 11.7 4.8 7.4 10.6 4.4

Knocknagashel 110 kV 12.0 14.9 5.5 9.7 8.4 3.4 12.2 13.9 5.1 9.8 7.9 3.2

Knockraha A 110 kV 7.9 57.8 22.4 8.8 55.8 22.5 19.3 14.6 5.8 21.6 15.0 6.1

Knockraha B 110 kV 7.9 57.8 22.4 8.8 55.8 22.5 7.8 38.7 14.9 8.5 39.8 16.0

Knockraha A 220 kV 8.7 31.2 12.3 9.7 33.1 13.6 8.1 21.4 8.4 9.1 24.2 9.9

Knockraha B 220 kV 12.0 24.6 9.9 12.3 24.1 10.1 11.2 18.0 7.2 11.5 18.9 7.8

Knockumber 110 kV 3.5 17.1 8.2 4.4 13.4 6.2 3.6 16.1 7.6 4.5 12.8 5.9

Lanesboro 110 kV 3.7 23.6 10.8 5.1 23.8 10.6 3.9 22.3 9.9 5.3 23.5 10.3

Laois 110 kV 5.9 31.2 13.4 6.4 39.1 16.8 6.3 25.9 10.8 6.7 33.1 13.9

Laois 400 kV 14.9 17.2 7.3 14.6 17.6 7.5 14.5 13.6 5.6 14.5 14.7 6.2

Letterkenny 110 kV 4.4 18.6 6.9 5.5 17.3 7.1 4.5 17.2 5.9 5.6 16.3 6.5



Limerick 110 kV 4.6 36.1 15.9 5.6 34.9 15.3 4.7 29.4 12.5 5.6 30.1 13.0

Lisdrum 110 kV 2.7 10.1 5.2 3.8 6.4 3.1 2.8 9.7 4.9 3.9 6.5 3.1

Lisheen 110 kV 3.6 7.9 3.8 5.2 5.8 2.6 3.7 7.4 3.5 5.2 5.6 2.5

Lodgewood 110 kV 8.6 23.4 8.5 9.0 28.8 11.2 8.8 20.5 7.2 9.2 25.6 9.8

Lodgewood 220 kV 9.2 18.5 7.4 10.7 18.1 7.5 9.1 15.0 5.9 10.5 15.4 6.3

Longpoint 220 kV 11.9 22.3 9.0 14.2 23.5 9.9 12.0 19.1 7.5 14.1 21.2 8.9

Louth 110 kV 9.9 49.5 19.1 10.7 61.1 24.2 10.4 44.6 16.6 11.1 54.0 21.1

Louth 220 kV 10.4 53.6 21.7 11.2 50.7 21.2 11.4 45.0 17.8 11.9 42.4 17.6

Macetown 110 kV 6.9 37.9 15.8 6.9 36.4 15.4 6.7 30.0 12.3 6.8 30.6 12.9

Macroom 110 kV 4.5 25.1 10.9 5.7 23.0 10.0 4.9 21.2 8.8 5.9 20.4 8.7

Mallow 110 kV 3.4 13.3 6.4 5.1 11.6 5.2 3.6 12.0 5.5 5.2 10.8 4.8

Marina 110 kV 6.3 46.5 18.6 7.0 49.9 20.7 6.1 31.9 12.8 6.6 37.4 15.6

Maynooth A 110 kV 10.9 34.9 13.8 11.7 42.4 16.9 10.9 28.9 11.2 11.7 35.7 14.2

Maynooth B 110 kV 8.2 41.7 16.9 10.2 39.3 15.9 8.5 33.8 13.4 10.2 33.7 13.5

Maynooth A 220 kV 10.5 50.3 20.2 10.7 45.3 18.9 10.9 36.0 14.1 11.1 35.5 14.6

Maynooth B 220 kV 10.6 56.5 22.6 10.6 50.8 21.1 10.8 38.0 14.9 10.9 38.2 15.7

Meath Hill 110 kV 3.7 20.2 9.4 5.0 17.1 7.7 3.8 19.1 8.7 5.1 16.3 7.2

Meentycat 110 kV 3.7 12.8 4.9 5.2 11.3 4.8 3.8 12.2 4.4 5.3 11.1 4.5

Midleton 110 kV 3.4 22.7 10.8 4.6 18.5 8.5 3.8 18.5 8.5 4.8 16.1 7.3

Moneypoint G1 400 kV 23.7 29.0 13.0 20.9 30.2 13.6 17.5 19.5 8.1 17.5 22.3 9.6

Moneypoint G2 400 kV 33.2 11.0 5.3 24.9 11.3 5.2 18.8 6.1 2.7 18.2 7.3 3.2


E-23




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Moneypoint G3 400 kV 23.7 29.0 13.0 20.9 30.2 13.6 17.5 19.5 8.1 17.5 22.3 9.6

Moneypoint 110 kV 13.9 24.6 9.6 16.0 24.1 9.6 12.9 21.0 8.1 15.0 21.3 8.4

Moneypoint A 220 kV 13.0 30.2 12.3 10.2 27.1 11.3 10.2 18.6 7.4 9.3 19.6 8.1

Moneypoint B 220 kV 15.7 53.4 21.8 12.7 61.2 25.3 12.3 31.6 12.3 11.4 39.7 16.1

Moneteen 110 kV 5.0 24.7 10.8 6.2 19.5 8.4 5.1 21.5 9.2 6.2 17.7 7.6

Monread 110 kV 4.0 16.4 7.7 4.9 15.7 7.1 4.1 14.4 6.6 5.0 14.4 6.5

Moy 110 kV 4.0 10.6 4.7 5.2 11.4 5.0 2.9 6.7 3.2 3.6 8.1 3.9

Muingnaminnane 110 kV 3.9 16.9 7.2 3.1 12.6 6.2 - - - - - -

Mullagharlin 110 kV 3.6 19.5 9.3 4.6 18.0 8.3 3.7 18.5 8.5 4.7 16.2 7.3

Mullingar 110 kV 3.5 14.8 7.2 4.9 14.7 6.6 3.5 13.1 6.3 4.9 13.6 6.1

Mulreavy 110 kV 7.4 12.5 4.8 7.4 6.3 2.6 7.1 11.1 4.2 7.3 5.8 2.4

Mungret A 110 kV 4.7 23.2 10.3 5.9 17.9 7.8 4.8 20.2 8.8 5.9 16.3 7.1

Mungret B 110 kV 4.7 23.2 10.3 5.8 18.0 7.8 4.8 20.3 8.8 5.9 16.4 7.1

Nangor 110 kV 14.8 41.2 16.1 7.0 42.9 18.1 14.0 33.9 13.0 7.3 36.8 15.3

Navan 110 kV 4.9 28.5 12.6 5.9 28.3 12.3 5.2 26.0 11.1 6.1 26.1 11.2

Nenagh 110 kV 2.6 7.1 3.7 3.8 4.4 2.1 2.7 6.5 3.4 3.8 4.1 2.0

Newbridge 110 kV 4.0 22.5 10.4 4.9 21.7 9.8 4.3 19.0 8.5 5.1 19.3 8.6

Nore 110 kV 4.7 21.0 9.5 5.4 15.8 7.0 3.6 12.4 5.9 4.4 11.5 5.3

North Wall 220 kV 16.9 58.8 24.2 9.5 61.8 25.3 11.2 27.5 11.0 9.2 33.7 13.9

Oldcourt A 110 kV 3.6 22.4 10.5 4.4 17.6 8.1 4.0 18.4 8.3 4.5 15.3 7.0

Oldcourt B 110 kV 3.6 22.6 10.6 4.4 17.8 8.2 4.0 18.5 8.4 4.6 15.4 7.0

Oldstreet 220 kV 15.6 29.3 12.3 12.9 30.3 12.7 12.8 19.0 7.8 11.8 21.7 9.1

Oldstreet 400 kV 15.9 23.0 9.8 10.9 19.8 8.3 13.5 16.8 6.9 10.7 15.9 6.6

Oughtragh 110 kV 3.7 10.3 4.7 4.9 6.8 3.0 3.7 9.2 4.1 4.9 6.3 2.8

Platin 110 kV 4.7 27.3 12.3 5.5 21.0 9.3 4.9 24.4 10.7 5.6 19.6 8.6

Pollaphuca 110 kV 3.2 6.2 3.1 4.7 5.5 2.5 2.7 4.7 2.4 4.0 4.7 2.3

Poolbeg A 110 kV 26.2 32.8 13.7 21.9 40.1 16.5 21.5 27.5 11.0 19.4 34.2 13.8

Poolbeg B 110 kV 26.1 32.7 13.7 21.9 40.0 16.4 21.5 27.4 11.0 19.4 34.2 13.8

Poolbeg A 220 kV 17.4 58.8 24.4 10.5 65.2 26.6 11.5 27.7 11.2 9.7 34.9 14.4

Poolbeg B 220 kV 14.7 46.4 19.2 13.1 50.4 21.1 12.5 31.2 12.5 12.1 36.4 15.1

Portlaoise 110 kV 4.3 26.5 12.1 5.3 22.8 10.2 4.7 22.7 9.9 5.5 20.5 9.0

Prospect 220 kV 11.7 40.7 16.2 10.0 36.7 15.2 9.8 24.3 9.5 9.3 25.7 10.6

Raffeen 220 kV 15.7 32.1 13.0 13.4 37.4 15.5 12.7 21.2 8.4 11.8 26.4 10.8

Raffeen A 110 kV 5.3 33.9 14.3 6.1 39.9 17.0 5.7 26.0 10.7 6.3 31.7 13.4

Raffeen B 110 kV 8.0 35.4 13.9 8.9 41.2 16.6 7.8 27.0 10.5 8.5 32.7 13.2

Ralappane 110 kV 10.0 45.6 17.1 10.3 39.7 15.7 9.6 35.5 12.9 10.0 33.3 13.0

Rathkeale 110 kV 3.5 16.0 7.6 4.6 9.8 4.5 3.6 13.9 6.5 4.6 8.9 4.1


E-24




Bus X/R

Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Ratrussan 110 kV 3.4 15.6 6.7 4.5 17.3 7.7 3.5 15.1 6.2 4.6 17.1 7.4

Richmond A 110 kV 2.9 10.8 5.5 4.0 7.7 3.6 3.0 10.2 5.0 4.1 7.4 3.5

Richmond B 110 kV 2.9 10.7 5.4 4.2 10.1 4.7 3.0 10.1 5.0 4.3 9.7 4.5

Rinawade 110 kV 4.9 24.2 10.8 6.0 17.3 7.5 5.2 20.9 9.1 6.1 15.8 6.8

Ringaskiddy 110 kV 5.6 27.5 11.6 6.0 26.5 11.4 5.8 22.0 9.1 6.1 22.4 9.5

Ryebrook 110 kV 5.3 29.8 13.1 6.0 20.7 9.0 5.4 24.7 10.6 6.1 18.6 8.0

Salthill 110 kV 3.8 22.1 10.4 3.6 22.3 10.8 3.9 19.0 8.6 3.8 19.8 9.4

Screeb 110 kV 3.3 4.9 2.5 4.3 3.0 1.4 3.3 4.6 2.3 4.3 2.9 1.4

Sealrock 110 kV 7.5 23.6 9.4 9.2 25.7 10.4 7.8 22.1 8.6 9.5 25.1 10.0

Sealrock 110 kV 7.5 23.6 9.4 9.2 25.7 10.4 7.8 22.1 8.6 9.5 25.1 10.0

Shankill 110 kV 3.3 17.6 8.0 4.5 16.1 7.3 3.4 16.8 7.4 4.6 15.7 7.0



Shellybanks A 220 kV 16.9 58.6 24.2 10.4 65.1 26.6 11.4 27.7 11.1 9.7 34.9 14.4

Shellybanks B 220 kV 15.6 53.6 21.8 12.7 62.4 25.8 13.1 34.9 13.8 12.0 43.5 17.8

Singland 110 kV 5.5 36.2 15.4 6.5 34.8 14.8 5.3 28.9 12.0 6.2 29.5 12.5

Sligo 110 kV 3.6 20.3 8.9 4.7 19.3 8.6 3.7 17.9 7.5 4.7 17.6 7.7

Somerset 110 kV 2.9 15.7 7.8 4.0 10.8 5.1 3.0 14.6 7.0 4.0 10.1 4.7

Sorne Hill 110 kV 3.3 6.3 2.6 3.9 7.5 3.4 3.3 6.1 2.4 4.0 7.3 3.2

Srananagh 110 kV 4.5 25.4 10.4 5.7 27.6 11.7 4.7 22.3 8.7 5.8 24.7 10.2

Srananagh 220 kV 7.2 11.8 4.9 9.8 9.7 4.0 7.2 10.6 4.3 9.8 8.9 3.7

Stevenstown 110 kV 4.2 13.4 6.3 4.7 8.8 4.0 4.5 11.9 5.4 4.9 8.4 3.8

Stratford 110 kV 3.3 9.2 4.6 4.3 7.1 3.3 3.1 7.5 3.7 4.1 6.3 3.0

Tynagh 110 kV 6.5 23.4 9.9 2.3 19.3 10.5 6.7 20.5 8.5 2.5 17.8 9.5

Tarbert 110 kV 34.6 45.1 19.3 36.4 42.9 19.0 20.7 28.4 11.1 23.9 31.6 13.0

Tarbert 220 kV 15.8 56.1 22.7 15.6 64.4 27.2 11.4 30.6 11.8 11.9 39.0 15.9

Tawnaghmore 110 kV 3.8 8.6 3.9 5.1 8.7 3.9 2.7 5.5 2.7 3.6 6.3 3.0

Tawnaghmore 110 kV 3.9 8.8 4.0 5.2 9.0 4.0 2.7 5.5 2.7 3.6 6.4 3.1

Thornsberry 110 kV 4.3 15.5 7.0 5.8 14.0 6.1 4.3 12.3 5.6 5.6 12.0 5.3

Thurles 110 kV 3.9 10.2 4.8 6.0 8.7 3.8 4.1 9.6 4.4 6.1 8.7 3.8

Tievebrack 110 kV 4.5 9.7 3.9 6.0 7.4 3.1 4.6 9.0 3.5 6.0 7.0 2.9

Tipperary 110 kV 2.8 12.1 6.2 4.0 7.1 3.4 2.9 11.3 5.6 4.1 6.8 3.2

Tonroe 110 kV 3.4 10.5 5.0 4.4 8.7 4.0 2.8 6.3 3.1 3.9 4.1 2.0

Trabeg 110 kV 6.0 45.1 18.2 6.1 47.7 20.2 6.0 31.5 12.6 6.1 36.3 15.3

Tralee 110 kV 5.0 24.1 9.6 6.4 19.2 8.0 4.8 19.5 7.6 6.1 17.2 7.1

Trien A 110 kV 4.6 20.4 8.3 6.3 17.2 7.2 4.9 17.9 6.9 6.4 15.9 6.6

Trien B 110 kV 15.9 20.4 7.5 12.9 14.6 5.7 15.7 18.7 6.7 12.9 13.7 5.3


E-25




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Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

X/R Ratio

Peak Make [kA]

Tot RMS

Break [kA]

Trillick 110 kV 3.3 6.9 2.8 4.0 7.4 3.3 3.4 6.6 2.6 4.1 7.2 3.1

Tullabrack 110 kV 6.5 16.9 7.2 7.2 13.1 5.5 6.6 15.0 6.2 7.3 12.0 5.0

Turlough Hill 220 kV 11.2 32.1 12.9 12.5 27.9 11.7 11.4 25.5 10.1 12.6 23.9 10.0

Tynagh 220 kV 14.9 32.2 13.2 17.0 34.9 15.1 10.1 17.7 7.2 11.4 21.8 9.1

Waterford 110 kV 5.5 29.1 12.3 5.9 29.0 12.5 5.0 21.0 8.9 5.5 22.8 9.9

Wexford 110 kV 3.8 14.7 6.4 5.1 13.4 5.9 4.1 13.0 5.4 5.3 12.5 5.4

Whitegate 110 kV 4.3 22.0 9.9 5.1 22.9 10.2 4.5 17.8 7.9 5.3 19.3 8.5

Woodland 220 kV 12.9 61.0 24.7 11.9 56.8 23.7 12.1 36.1 14.4 11.8 38.3 15.9

Woodland 400 kV 17.3 28.2 12.2 14.2 25.7 11.0 15.8 21.5 9.0 13.9 20.3 8.6

additional information on oPPortunities

APPENDIX F


F-1

APPENDIX F ADDITIONAL INFORMATION ON OPPORTUNITIES

The t ransmiss ion networ k is des igned to prov ide a safe , re l iab le and ec onomic t ransport

s e rv i ce f or pow e r f r o m sou r c e t o d em a n d . T h e Transmiss ion P lanning Cr i ter ia (TPC) pr ov ides

a p lanning f r amewor k by which a balance can be achiev ed between re l iabi l i ty and economy.

A c hi ev i ng t h i s b al a nc e m e a n s th at u n d e r cer ta in c i rcumst ances some level o f const raints

w i l l ex is t i n t h e syst em.

The Transmissi on System Operat or (TSO) c on s t a n t l y r ev i ew s s y st em p e r f o r man c e a s

c i rcumst ances change. For ex ampl e, the connect ion o f new generat ion or demand to the

g r i d , a d di t i ona l t o t h e c ur r e n t f or e cas t s a n d a ssumpt ions, or new interconnect ion t ransfers ,

w i l l a l ter the expect ed pow er f l ows. Constr a i nts wi l l a r ise i f the new power f l ows exceed

p la nne d g r id c apaci ty .

In desi g ni ng out th ese const r ai nts th e TS O w i l l ta k e ac c o u nt o f th e f o l l o wi n g :

• The extent of the constra int ;

• The impact on system secur i ty ;

• Th e ov er al l ec onomi cs of t h e op er at i on o f th e s ys tem;

• The cost o f the so lut ion;

• T h e l e a d -t i me o f t h e s ol ut i o n .

The anal ysis o f t ransfer capabi l i t ies descr ibed i n C h a pt e r 8 i d e n t i f i e d a num b e r o f p ot e n t i a l

s y s t e m c o n st r ai n t s th at c o u l d l i mi t pow e r f l o w s ar is ing f rom new demand connect ions. Most

o f thes e have been ident i f i ed prev ious ly and are be ing managed by the TSO.

T h e s e p ot e nt i a l t r a n s mi ss i o n c o n st r ai n t s ar e pr esented in the table below. The f i rst co lumn

in each table prov ides a c ross- re ference to th e ITC resul ts tables in Ch apter 8 . The second

c o l u mn des cr i bes p o tent i a l l y o v er l o ade d c i r c ui t s o r n a m e s o f s t a t i o n s a t w h i ch l o w v o l t a g es

p o t e n t i a l l y o c c u r f o l l o wi n g p a rt i c ul a r o ut ag e s . T h e t h i rd co l u m n l is t s t h e c i r c u mst a n c e s

under wh ich the ov er loads or vol tage problems occur , thereby l imi t ing the ITC. For

c o n s t r a i nt s f o r wh i c h pro j e ct s h av e a l r e a d y b een i n i t i a ted , t h e f i n al c olum n p r o vi d es t h e

r e a d er w i t h th e C P n u m b er o f t he c a pi t a l pr oj e ct d e s ig n e d t o re l ie v e t h e c on s t r a i n t . Th is c a n

b e c r o s s -r e fer e n c e d ag ai n s t th e d eta i l e d d e s cr ip t i o ns o f t he p l a n n e d pr o j ec t s pr ovi d e d i n

Sect ion B-2 o f Appendix B.


F-2

T a b l e F - 1 L i st o f P o ten t i a l N et w or k C on s t r ai n ts for wh ic h th e TSO h a s i n i t ia t e d Pr o je c ts

ID P o t e nt ia l O ve r l oa d / V o l ta ge P r o bl e m

C i r c u ms t a nces Comment

P1 Athlone-Shannonbridge 110 kV line

Overload can occur for an outage of the Lough Ree Power generation station, Cashla-Prospect 220 kV line or Cashla-Flagford 220 kV line.

Capital projects CP261 and CP552 relieve these constraints.

P2

Carrickmines T2101 Overload can occur on either Carrickmines 220/110 kV transformer for an outage of the other. A trip-maintenance outage of both transformers can lead to voltage instability.

Capital projects CP483 and CP513 relieve these constraints.

Carrickmines T2102

Voltage Instability

P3 Cashla T2104

Due to a limitation of ancillary equipment, an overload can occur for a trip-maintenance outage of both of the other Cashla 220/110 kV transformers.

Capital project CP322 relieves this constraint.

study methodsG.2 incremental transfer capability studies for demand

APPENDIX G


G-1

APPENDIX G STUDY METHODS

G.1 INCREMENTAL TRANSFER CAPABILITY STUDIES FOR DEMAND

G.1.1 Background

Trans f er l imi t an alys i s was used i n th i s Tr ansmiss ion Forecast Stat ement (TFS) to determine

the Incrementa l T ransf er Capabi l i ty ( ITC) o f th e gr id at a number o f locat ions on the gr id .

The ITC ca lcu lat ed is a measure of the t ransf er c a p a bi l i t y r em a i n i ng i n t h e ph y si c al g r i d for

f u r th er c o mme r ci a l a ct iv i t y ov e r and a b o v e a l r ea d y a n t i c i p at e d u s es. I t pr o v i d es a n

indicat ion o f the f lex ibi l i ty o f th e gr id to accommodate future demand incr eases in selected

a r e a s wi th o ut t h e req u ir eme n t f or f u r th e r r e i n f or ce m e n t s .

The t ransfer analysis is in tended as a pre- feasib i l i t y ind icat ion o f opportuni ty for incr eased

d e m a n d s . Th e m et h o d f o r d et ermi n i ng I T C c l os el y a l i g n s wi th p r e - f e as i bi l i t y s t udy

t e ch n i q ue s .

G.1.2 Planning Criteria as Applied in Transfer Limit Analysis for Demand

In prev ious T ransmiss ion Forecast St atements the appl icat ion o f p lanning s tandards for the

analyses o f demand and generat ion was the same in a l l respects except for the

c o n t i ng e n ci es c o n si d e r e d a n d v ol t a g e a n a l y si s . I n t h e g e n er at i o n s t udi e s, t r i p - m a i nt e na n c e

(N-1 -1 ) cont ing encies were not considered. An assumpt ion was made that the hypothet ical

g e n e ra t or cou l d b e c on s t r ai n e d dow n o r o f f d u r i n g t r an s m i s si o n c i r cu i t m a i n ten a n c e .

However , demands are not d ispatchabl e , and so i t i s not acceptable to assume that the

hypothet ical demand may be const rai ned of f du r ing a maintenance outage. I t i s necessary ,

ther efor e , to assess the networ k per formance against st andards for t r ip -maintenance

c o n t i ng e n ci es i n t h e a na l y si s o f i n c r e a sed d em a n d s . T h e r e a s o n v ol t a g e a n a l ys i s w a s

per for med as par t of the ITC s tudies is becaus e the addi t ion o f demand is l ike ly to impact

o n l oc al v ol ta g e s .

G.1.3 Method for Calculating Transfer Limits for Increased Demand

D C l o adf l o w t e ch n i q ue s w e r e us e d t o s cr e e n f o r cr i t i c al c o nt i ng e nc i e s a n d th e r m al

o v e r l o ads , fo l l o w e d b y AC l o a d f l ow st u d i es t o c on f i r m t h e r es u l t s o f t h e D C l o a df l o ws a n d t o

ident i fy vol tage l imi tat ions. The network was a l s o t es ted ag ai ns t v ol t ag e st a nda rds f or a

r a n g e o f cr i t i c a l c o n t i ngen c i e s .

T ransfer s were consider ed between the “D ubl in” , “Norther n I re l and” and “South”

generat ion bl ocks desc r ibed in Tabl e G-1 in Se ct ion G .1 .3 .2 and the twenty-n ine 110 kV “ test

n o d e s ” s el ec t e d f or a na l y s i s .


G-2

T h e i n i t i a l g e n e r a t or d i sp a t ch e s f or t h e t r a n s fer capabi l i ty s tudies are pr esented in Table D-

4 i n A p p e n di x D . G e n e rat o r s w er e mo d e l l e d wi th t h e i r m a xim u m o u t p u t e q u i v al e nt t o t h ei r

Maximum Cont inuous Rat ing (M CR) . As w i nd energ y is v ar i a ble , i t c a nnot be r e l i ed upon t o

s erv e dema nd. As s uch , l oc al wi nd gener a t i on w a s sw it ch e d o u t i n t he v ic i ni t y o f th e t e st

node . These d i spatc hes, wi th wi n d g e n e ra t i o n l o c a l t o t he t e s t n o d e sw i tc he d o u t , w e r e

used for s ing le cont ingency (N-1 ) s t udies . For N-G-1 and N-1 -1 cont ingencies , the centra l ly -

d i s p at ch a ble g e n er a t i o n l o ca l t o th e t e s t n o d e wa s m a xi m is ed t o i t s M C R v al u e , t o cre a t e a

more favourable d ispatch for the maintenance case.

To calcul at e the ITC, demand at 95% power fact or was added at the test node in increasi ng

amounts . This was balanced by an equivalent inc r e a se i n gen e r a t i o n out p u t f r o m ex i st i ng

g enerat i on w i th i n one of th e t hr ee g ener a t i on b l oc ks. Thi s i s i l l ust r ated i n F ig ure G -1 . In

c a s e s wh e r e f u l l ca p a ci t y w a s r e a ch e d o n a l l g en erat ion uni ts wi th in a generat ion b lock, the

m a x i m u m cap a c i t y w as inc r e a sed t o a l l o w f ur th er t ra n s f er . T h e l i m it f or inc r e a sed t rans f e r s

f rom the generat ion bl ock to the test node was establ ished by ch ecki ng the post -

cont ing ency per formance of the g r id ag ains t thermal and then vo l tag e st andards. The

p r o c es s w a s t h e n r ep e a ted f or t h e t w o r e m ai n i ng gen e r a t i o n b l o c k s .

P r o bl e m s on t h e gr i d w e r e n ot c on s i d e re d l imi t i ng unl ess th ey w ere sensi t iv e t o the

i n c r e me n t al t r a n sf e rs u n d e r e x a mi n at i o n . F o r th e p u r p o s e s of t h e s t udi es f o r t h i s T FS t h e

s e n s i t i v i t y fa c t or u s e d w a s a c h a ng e i n c i r c ui t l o a di n g o f 5 M W o r m o r e f o r a 1 00 M W

t ransfer . In addi t ion, over loads on the 220 and 400 kV networks were considered sensi t ive

t o t h e t r a ns f e r o n l y i f th e y w e r e i n c r ea s e d by 4 M W o r m o r e . V ol t ag e p r o bl e ms w er e

c o n s i d er e d sen s i t iv e i f the v ol t ag e dro p p e d b y m or e t ha n 3 % for ev er y 1 00 M W .

To ass ist the reader , the in format ion f rom th is analysis is presented concise ly by combining

the re s ul ts of th e IT Cs f rom the “ Dubl in” , “Nor thern I re land” and “South” generat ion b locks

to each of the 29 selected 110 kV s tat ions. Th is prov ides an indicat ion o f the capabi l i t ies

f or incre ased d eman d at each s tat ion. When consider ing s ing l e cont ingencies (N-1 ) on an

i n t ac t n e t wor k t h e m i nim u m I T C f r om D u bl i n , Nor th e r n I r e la n d o r th e s o u t h wa s ch o s e n .

H o w ev e r , whe n c o n s i d er ing t r i p - m ai nt e n a n c e cont ing encies (N-1 -1 ) , the greater o f the ITCs

f r o m D u bl i n , N o r th e r n I re l a n d or th e s o u t h wa s c h o s e n . Thi s w a s b a s ed o n t h e as s um p t i o n

that less onerous generat ion d ispatches coul d be scheduled to accommodate maintenance

ou tag e s . The r esul ts ar e p r esented in Sect ion 8 .1 o f Chapter 8.


G-3

F ig u r e G - 1 I l l u s t r at i o n of I n c r e m e nt a l T r a n s f er C apa b i l i t y St u d y M et h od for D e m a n d

G.1.4 Example: Calculation of Capability for Demand at Shankill 110 kV Station

This sect ion prov ides an exampl e of the analysis o f the capabi l i ty o f Shanki l l 110 kV st at ion

to accommodate incr eased demand at summer peak 2013 . The exampl e i l lust rates the s teps

taken towa rds der iv ing the demand opportuni ty at Sh anki l l 110 kV s tat ion.

The assessment was car r ied out by s imulat ing th e n e t w or k f or s u m m e r p eak 2 0 1 3 u si ng t h e

demand forecasts presented in Table C-2 in Ap p e n d i x C a n d t he r e l ev a nt gen e r a t or d isp a t ch

f r o m Tab l e D-4 i n A pp e n di x D .

D u e to i t s va r ia b l e n a t ur e , w i n d g e ner a t i o n c a n no t b e r e l i e d o n t o m e et th e d e ma n d a t a l l

t i m e s . T h er ef o r e , t o pr ep a r e t h e m od e l f or t e s t ing th e ca p ab i l i t y f o r a dd i t i o n al d e ma n d a t

Sh anki l l , a l l wi nd g enerat i on i n the nor th-east i .e . , in the v ic i n i t y o f Sh anki l l , wa s sw i tc hed

of f .

T h r e e s et s of s t u d i es w er e c a rr ied o u t , w i t h th e e x t r a d e m an d i n e a c h m e t b y i n c re a s i ng

generat ion in one or o ther o f the “Dubl in” , “Northern I r e l and” and “South” generat ion

b l o c ks . F or e a c h s t u d y in t u r n , t he D C l oa d f l o w s c r ee n i ng ana l y si s wa s u s e d t o a d d a t e st

demand to Shanki l l 110 kV st at ion and to vary i ts s i ze between zero and 100 MW. A n

equivalent amount o f generat ion was increased in each generat ion b lock in order to meet

the incr eased demand at Shanki l l , wh ich set up incremental power t ransfers between each

generat ion b lock and Sh anki l l . The analysis test ed a l l c ombi nat i on-pai rs o f c i rcu i t an d

Overloaded Circuit Resulting

From Transfer

Test Node

Load Increased At

Test Node

Generation Increased In

South


G-4

g e n e ra t or o ut a ges a n d i de n t i f i e d t h e m o s t r es tr ic t i v e o ut ag e com b i n a t i o n s a n d r e c or d ed t h e

leve l o f ex t ra demand at which the networ k went outs ide st andards.

T h e 2 5 w o r st c o m b i n at ions w e r e th en m o r e c l ose l y ch ecked in AC loadf low studies . In th is

e x a m pl e , r eg a rdl es s of w he th e r the e xt r a d em a n d w a s sup p l i e d f r om D u bl i n , N o r th e r n

I re l and or the south, an outage o f the Rat russan-Shanki l l 1 1 0 k V l i ne d u r i ng th e

m a i n t e n a nc e o u t ag e o f the A rv a - S ha n k i l l N o . 2 1 10 k V l i ne w ou l d res ul t i n a 1 0 % o ve r loa d o n

the Arva-Shanki l l No. 1 110 kV l ine when the dema nd a t Sh anki l l w a s i nc r ea sed by 9 0 MW .

Th is was ther efor e the l imi t o f addi t ional deman d p e r m i s si bl e a t S h a n k i l l t a k i ng a cc o unt o f

ther mal ov er load s tandards.

T h e n e t w or k w a s n e x t t e s t e d ag a i ns t v ol t ag e s tandards wi th the 90 MW of addi t ional

d e m a n d m o del l e d at Sh ank i l l . A l l p os s i bl e c i rc u i t a n d g e n e rat o r o ut ag e com b i n a t i o n s w e r e

s imulated and vo l tag es checked. The anal ys is showed that the syst em remained wi th in

vo l tag e s tandards wi th the addi t ional demand c on n e c t e d a t S h a n ki l l . A s s u c h , t h e l i m i t o f

a ddi t i onal dema nd p er mi s si bl e at Sha nki l l 110 kV s tat ion is 90 MW for summer peak 2013.

abbreViations and GlossaryH.1 abbreviations

H.2 Glossary

APPENDIX H


H-1

APPENDIX H ABBREVIATIONS AND GLOSSARY

H.1 ABBREVIATIONS

CCG T Combined Cyc l e G as Turbine

CER Commission for Energy Regul at ion

CHP Combined Heat and P ower

D O D i st i l l at e O i l

D S M D e m a n d Si de M a na g e m en t

D S O Dist r i but i on System Operator

ES B E lect r ic i ty Supply Board

ESRI Economic and Soc ial Research Inst i tut e

G A R G e nera t i o n A d e q u a c y Rep o r t

H F O H e av y F ue l Oi l

H V D C H igh V ol t a ge Di r ec t C u rr ent

ITC Incrementa l T ransfer Capa bi l i ty

LFG Land F i l l Gas

MCR Maximum Cont inuous Rat ing

M E C M a xi m u m E xp o r t C a p ac i ty

MVA MegaVol t -Amperes

NI Nor thern I re land

NTC Net Tr ansfer Capaci ty

N IE Nor thern I re land E l ect r ic i ty

p .u . Per Uni t

PST Phase Shi f t ing Tr ansformer

RES Renewable Energy Schemes

RMS Root Mean Square

S E M S i n gl e E l e ct r i c i t y M ar k et

SONI System Operator Nor thern I re l and


H-2

SVC Stat ic Var Compensator

SP Summer Peak

SV Summer Val ley

TFS Transmiss ion Forecast St atement

TRM Transfer Reserve Marg in

TSO Transmiss ion System Operator

TTC Tota l T ransfer Capaci ty

WDRI Winter Demand Reduct ion Incent ive

WP Winter Peak

WPDRS Winter Peak Demand Reduct ion Scheme


H-3

H.2 GLOSSARY

Act ive Power The pr oduct o f vo l tag e and the in -phase component of

a l ter n at i ng cur r e nt m e asur e d i n M ega W a tt s ( MW ). Wh e n

c ompounded wi th t he f l ow of ‘ r eact ive power ’ , whi ch i s

m e a s u r e d i n M eg a V ol t - Am p e r e s R e a ct iv e ( Mv a r ) , t h e

r e s ul t a nt i s m e a s u r e d i n M eg a V ol t - Am p e r e s ( M VA)

B o r d G ái s B o r d G ái s É i r e a n n (B o rd G á is ) w a s e s t a bl is h e d i n 1 9 7 6

and is a commerc ia l State body operat ing in the energy

indust ry . Bord Gáis is responsibl e for the supply ,

t ransmi ssion and d ist r ibut ion o f natural gas in the

Republ ic o f I r e land.

Busbar The common connect ion point o f two or more c i rcu i ts .

Capaci tor An i tem of p lant normal l y u t i l i s e d o n t h e e l ec t r i c al

n e t w o rk t o sup p l y r ea ct iv e p o w er t o l o a d s (g e n e ra l l y

loca l ly ) and ther eby support i ng th e local area v ol tage.

Commi ssion f or Energ y Reg ul at i on Th e Commi ssi on f or Energ y Reg ul at i on i s th e r eg ul ator

for the e l ec t r ic i ty and natural gas sectors in I r e land. The

C E R w a s i n i t i a l l y e st a bl is h e d a s th e C o m m i s s io n f o r

E l e ct r i c i t y Reg ul a t i o n u n d e r t he E l ec tr i c i t y R eg ul at i o n

Act , 1999. Th e funct ions o f the CER al ong wi th i ts name

w e r e ch a ng ed b y t h e G a s ( I n t er i m R egul at i o n ) A ct , 2 0 0 2 .

U nder th at Ac t , th e r emi t o f th e CER w as ex panded t o

i nc l ude th e reg ul at i on of t h e natur al g as sec t or and th e

name changed to the Commiss ion for Ener gy Regul at ion.

C i r c ui t An e lement of th e t r ansmi s si on system th at carr ies

e lect r ica l power .

Combined Cyc le Gas Turbine A col lect ion o f gas turb ines and s team uni ts; wast e heat

f rom the gas turb ine(s ) is passed through a heat

r e c ov e r y b oi l e r to g e n e rat e st e a m f or t h e st e a m

t u r bi n e ( s ) .

Combined Heat and Power A pl ant designed to produce both heat and e l ec t r ical

power f r om a s i ngle heat sour ce.


H-4

Constraint A t ransfer l imi t imposed b y f i n i t e n et w o rk c a p ac i t y .

Cont ingency The unex pected fa i lur e or outage of a syst em comp onent ,

such as a generat ion uni t , t ransmiss ion l ine, t ransformer

or ot her e lect r ical e lement . A cont ingency may a l so

inc lude mul t ip le components , which are re lated by

s i tuat ions leading to s i mul taneous component outages.

D a t a Fr e e z e D a t e T h e da t e o n w hi ch t h e T ra n s m i s si o n F o r e ca s t S tat e m e n t

d a t a w as ef fec t i v el y “ f r oz e n ” . C h a ng e s t o n et w ork

c h ar a ct e r i st ic s m a de af t er t h i s d a te di d n ot f e at u re i n

the anal yses car r ied out for th is T ransmissi on Forecast

S t a t e m e nt .

D eep Rei nforc ement Ref er s t o netw or k r e i nf orc ement addi t i onal t o th e

s h al l o w c o nne c t io n t h at i s r e q ui re d to a l l ow a n ew

g e n e ra t or or d e m a n d t o o p e r at e a t ma x i m u m ca pa c i t y .

Demand The peak demand f ig ures in Tabl e S-1 in the Summary

re fer to the power that must be t ransported f rom gr id-

connected generat i on s tat ions to meet a l l cust omers '

e l e c t r i c i t y r eq u i r e me n t s. Th ese f i g ur es i nc l ude

t r a n s mi s si on l os s e s .

D e m a n d - S i de M a na g e m en t T h e m o di f i cat i o n o f n o r ma l d e m a n d pa t t er n s u s u al l y

t hr o u gh th e u s e o f f i n a nc i al i n cen t i ve s

E i rGr i d E i rg r i d p l c i s th e st at e-ow ned company w hi ch has been

e s t a bl ish e d t o t a k e o n t he r ol e a n d r es p o n s i bi l i t i es o f

T ransmiss ion System Operator in the Republ ic of I re l and

as wel l as Market Operator of the wholesal e t rading

system.

E m b e d d e d G e n e r a t i o n R e f e r s t o g en e r a t i o n th at i s c o n n e ct ed t o th e d is t r i b ut i o n

system or at a cust omer ’s s i te .

G at e 2 T h e t e r m g iven t o th e gr oup - p r o ce s sin g sc hem e th a t

appl ies to approx imat ely 1 ,300 MW of renewable

generat ion seeking connect ion to the t ransmissi on and

d is t r ibut ion systems.


H-5

G at e 3 T h e t e r m g iven t o th e gr oup - p r o ce s sin g sc hem e th a t

appl ies to approx imat ely 10,00 MW of generat ion seeking

c onnec t i on to th e t r ansmi s si on and di s t r ibut ion systems.

G enerat ion Dispatch The conf ig urat ion of outputs f rom the connected

g enerat i on uni t s .

Gr id The t rans miss ion system is a meshed network of h igh

vo l tag e l ines and cabl es (400 kV, 220 kV and 110 kV) for

t h e t r a n s mi ss i o n of b ul k e l e ct r i c i t y sup p l y ar o u nd

I r e l a n d . Th e g r i d , e l e ct r ic i t y t r a n s mis s i o n n e tw o rk , a n d

t r a n s mi s si on s y s te m ar e u s e d i nt e rch a n ge a bl y i n th is

T r a n s m i s s i on F o r ec a st St a t e m e nt .

G r i d C o d e T h e Gr i d C o de is d es ig n ed t o c ov er a l l ma t er i a l t ec h ni c al

aspect s to the op erat ion and us e of the t ransmissi on

system. The code was prepared by the TSO (pur suant to

S e c t i o n 3 3 of th e E l e ct r i c i t y R e g ul at i on A c t , 19 9 9 ) a n d

approv ed by the CER. The Gr id Code is ava i labl e on

www.eirgrid.com.

Incrementa l T ransfer Capabi l i ty A measure of the t ransfer capabi l i ty remaining in the

p h y si c al gr id f or f u r t h er c o m m er ci a l a c t i v i t y ov e r a n d

above ant ic ipated uses.

In terconnector The t ie l i ne, fac i l i t ies and equipment th at connect t h e

t ransmi ssion system of one independent ly suppl ied

t r a n s mi s si on n e t w or k t o th a t o f a n oth e r .

Loadf low Study car r ied out to s i mulate the f low of power on the

t ransmi ssion system g iven a generat ion di spatch and

s y s t e m l oa d .

Maximum Cont inuous Rat ing The maximum capaci ty (M VA) modi f ied for ambient

t emperat ur e c ondi t i ons th at th e c i rc ui t c an sust a in

indef in i te ly wi thout degradat ion of equipment l i fe .

T h e M C R of a g e n er at o r is th e ma xi m um c a pa ci t y (M W )

modi f i ed for ambient temperat ure condi t ions that the

g enerat i on uni t c an susta i n i ndef i n i te l y w i th out

degradat ion of equi pment l i fe . A l l generat ion capa ci ty


H-6

f ig u r es i n t h i s Tr a n s mi s si on Forecast Statement are

maximum cont inuous rat ings (def ined as i ts MCR at

10°C ) , ex pr es s e d i n ex p or t e d t er m s i .e . , g e n e ra t i on u n i t

o u t p u t l e s s th e u ni t ' s o wn l oa d .

Maximum Export Capaci ty The maximum export v alue ( MW ) p r ov i d ed i n ac cor d a n c e

w i th th e g e ner a t or ’ s c o nne c t io n ag ree m e n t . Th e M E C s a r e

c o n t rac t v al u e s whi ch t he gen e r at o r c h o o se s t o cat e r f or

p e a k i ng u n der c e r t a i n con d i t i ons th at ar e not normal l y

achiev able or sustai nable e .g . , a CCGT p lant can produce

g r eat er o ut pu t at l ow e r tem p e r at u r es.

N o d e C o n n e c t i ng p o i n t at w hic h s ev e r al c i r c ui t s m e et . N o d e

a n d st a t i o n a r e us e d i nter ch a n ge a bly i n th is

T r a n s m i s s i on F o r ec a st St a t e m e nt .

P a ram e tr ic Ana l y si s ( P - V ) c ur v es A p ar a m et r i c s t u d y i n v olve s a s er i es of p ow e r f l o ws th at

moni tor the changes in one set o f power f l ow var iables

w i t h r es p e ct t o a n o t h er i n a s y s t e ma t i c f a shi o n . In th i s

T r a n s m i s s i on F o r ec a st St a t e m e nt t h e t wo v ar i a bl e s ar e

vo l t ag e and ITC.

P e r U n i t (p . u. ) R a t i o o f th e a c t u al e l e ct r i c al q u a n t i t y t o th e s el e ct e d

b a s e q ua n t i t y . T h e b a s e q u a n t i t y u s ed h er e f or

c a lc ul a t i o n o f p er u n i t imp e d a n c e s is 1 0 0 M VA .

Phase Shi f t ing Tr ansformer An i tem of p lant e mp l o y ed o n t he e l ec t r i ca l n e two r k t o

c o n t r ol th e f l o w o f a ct i v e p o w er .

P ow er Fact or Th e pow er f ac t or o f a l oad is a rat i o of th e act iv e pow er

r e q u ir e m e nt t o t h e r e a ct iv e p o w er r e qui r e m e nt of t h e

l o a d .

React ive Compensat ion The pr ocess o f supply ing reac t ive power to the networ k.

Reactor An i tem of p lant employed on the e l ec t r ica l network to

e i th er l i mi t sh ort c i r c ui t l ev el s or prev ent v o l t age r i se

d e p e n d i ng on i t s i n st al lat i o n a n d c o nf ig u r at ion .

S h al l ow Conne c t io n S h al l ow Conne c t io n means th e l oc al c o nnec t i o n as s e t s

requi red to connect a cust omer to the t ransmissi on


H-7

s y s t e m a n d w h i ch ar e f or t h e s pe ci f i c b e n e f i t of t h at

p a r t i c ul ar c us t o m e r .

S i n gl e E l e ct r i c i t y M ar k et I n N o v e m b er 2 0 0 4 th e g ov e r n m e nt s of th e R e p u bic o f

I re l and and the UK announced the future establ ishment

o f a S i ngl e E l e ct r i c i t y Mar k e t on the is land of I re land.

T h i s wi l l repl a ce t h e c ur re n t bi l a t er al t r a d i ng m o del i n

I re l and and is due to commence in November 2007.

F u r th er d et ai l s c a n b e f ou n d o n t h e Al l I s l a n d P r oj e ct

websi t e , www.al l is l andproject .org.

Spl i t Busbar Refers to the busbar (s ) a t a g iven substat ion wh ich is

o p e r at e d e l ec t r i c a l l y s e pa r ated. Busbars are normal ly

s p l i t t o l i mi t s ho rt c i r c ui t l ev e l s or t o m a i nt ai n s ec u r i t y

o f s up pl y .

S t a t i c V ar Com p e n s a t or D e vi c e whi ch pr ov i de s fa s t a n d c o n t i n u o u s c a pac i t iv e

and induct ive react ive power supply to the power

system.

S u m m e r Va l ley T h i s i s t he mi n i m u m s y ste m d e m a n d . I t oc c ur s i n th e

p e r io d M a rch t o Sep t e mb e r , i n c l u sive .

Summer P eak This is the ma ximum sy stem demand in th e per i od M arc h

t o S ep t e m b er , i n c l u si ve .

Tee Connect ion U nswitched connect ion int o ex is t i n g l i n e b et w e e n t wo

other s tat ions.

Tota l T ransfer Capabi l i ty The tota l capaci t y ava i lable on cr oss-border c i rcu i ts

between the Republ ic o f I r e land and Northern I re land for

a l l f low s, inc luding emer genc y f low s that occur af ter a

c o n t i ng e n c y i n e i th er s yst e m .

T ransfor mer An i tem of eq uipment connect ing busbars a t d i f ferent

nominal vo l tages. (see a lso Phase Shi f t ing T ransf or mer )

T ra ns mis s ion In ter fac e St at i on A s ta t i o n t hat i s a p o i nt of c o n n ec t i o n b e tw e e n t he

t ransmi ssion system and the d ist r ibut ion syst em or

d i r ec t l y - c o nn e c t e d c u st ome r s .


H-8

T ra ns mis s i on Losses A smal l pr opor t ion of ener g y is l ost mai n l y as h eat w hi l s t

t ransport ing e lect r ic i ty on the t ransmissi on system.

T h e s e l os s e s a r e k n ow n as t r a n s mi s sio n l os s e s . As t h e

a m o u n t of ene r g y t r a n smi t t e d i n cr ea s e s , l o s s e s a l s o

i n c r ea s e .

T ra ns mis s i on Peak The peak demand that is t ransported on the gr id . The

t r a n s mi s si on p e a k i nc l ude s a n e st i ma t e o f t r a n smi s si o n

l o s s es .

T ransmiss ion P lanni ng Cr i ter ia The set o f s tandards that the t ransmiss ion syst em is

des igned to meet .

U p rat i ng To i ncr ease th e r at i ng of a c i rc ui t . This is ach i ev ed by

increas ing ground c l earances and/or repl acing

c o n d u c t or , tog e th er w i t h a n y c ha n g es t o ter mi n al

equipment and support s t ruct ures .

Winter Demand Reduct ion Incent ive

Tar i f f

T h i s tar i f f pro v i de s l arg e E S B c us t o me r s w i th a f in a n c i al

incent ive to reduce thei r demand ov er weekday peak

h o u r s i n w i nt e r .

W i n te r Pea k T h i s i s t he ma x i m u m a n nua l s y st e m dem a n d . I t occ u r s i n

t h e p er i o d Oc t o b er t o F eb r u a r y , i n c l us i ve .

Winter Peak Demand Reduct ion

Scheme

T h i s sc h e m e w a s i n t ro d uc e d i n w i nt er 2 0 03 / 04 as a n

incent ive to business customers to reduce consumpt ion

dur ing system peak hours (5 -7pm) in winter months.

references

APPENDIX I


I-1

APPENDIX I REFERENCES

The fo l l ow ing documents are re ferenced in T ransmissi on Forecast Stat ement 2010-2016:

• E l e ct r i c i t y Reg ul a t i o n Act , 1 99 9 . Th i s a c t p r ov ides th e r eg ul at o r y f r a m ewo r k f or th e

in t roduct ion o f compet i t ion in th e generat i on and supply of e lec t r ic i ty in I re l and.

The Act prov ided for the establ ishment o f the Commiss ion for Energy Regul at ion

( C E R ) ( p r e v io u s l y c al l e d t h e C o m m i ss i o n f o r E l ec t r i c i t y R egul at i o n ) a n d g a v e i t th e

n e c e s s ar y pow e r s t o l i cen c e a n d r eg u l a t e th e gen e r a t i o n , d i s t r i b ut io n , t r a n s mi s si on

a n d s u ppl y of e l e ct r i c i t y . A va i l a bl e on w ww . c er . i e .

• G enerat i on Adequac y Repor t , 2010-2016 . The TSO issued th is repor t in November

2 0 0 9 . I t s ma i n p ur p o s e i s t o i n f orm m a r ket par t i c i p a nt s , r e g ul at o r y ag e n ci e s a n d

pol icy makers o f the l ike ly mi n imum genera t ion capaci ty requi red to achiev e an

a d e q u a te s up p l y a n d d em a n d b a l a nc e f o r e l e ct r i c i t y f or t he p e r i o d 2 0 10 t o 2 0 1 6 .

Avai lable on www.ei rg r i d.com.

• Grid Code Vers ion 3 .1 , May 2008. The Gr id C o d e c o v er s t ech n i c a l a s p ect s r e l at i ng t o

the o p er at i on an d use o f the t ransmissi on syst em, and to p lant and apparatus

connected to the t ransmission syst em or to the d ist r ibut ion system. Av ai labl e on

w w w . ei rgr i d .c o m.

• Transmiss ion P lanning Cr i ter ia , October 1998. This document sets out the techni cal

s tandards by which the adequacy o f th e gr id is determined. Ava i lable on

w w w . ei rgr i d .c o m.

• Statut ory Inst rument no. 445. These Regulat i o ns g iv e l eg al e f f e ct t o Di rec t i v e N o .

96/92/EC of the European Par l iament and of the Counci l o f 19 t h D ec em b e r 1 9 96,

c o n c e r ni n g c o m m o n r u l e s f o r t he i n t e r n al m a r k e t i n e l e ct r i c i t y , n o t a l rea d y

impl emented by the E lect r i c i t y R e g ul a t i o n A c t , 1 9 99 , b y p r ovi di n g f o r the

des ignat ion o f a T ransmissi on Syst em Oper at or , the des ignat ion o f a D is t r ibut ion

System Oper ator , and the unbundl ing o f the accounts o f e lect r ic i ty under taki ng s,

a n d o th er ma t t er s . A va i l a b l e o n www.cer . i e .

• T S O L i c e nc e. O n J u n e 2 9 t h 2006, the CER issued a T ransmiss ion System Operat or

(TSO) L icenc e to E i rGr id pl c . pursuant to Sect ion 14(1 ) (e ) o f the E lec t r ic i ty

R e gulat i on Act , 1999, as i n ser ted by Regulat ion 32 o f S. I . No. 445 o f 2000 –

E u r o p e a n C om m u n i t ie s ( In t e r n al M ar ke t i n E l ec t r ic i t y ) R e g ul at io n s 2 0 0 1 .

• Del iver i ng a Sustainable Energy Future for I r e land. Government Whi te Paper on

e ne rgy pol i cy out to 2 02 0, publ ished by the Depar tment of Communicat ions, Mar i ne

a n d N at u r al R e s o u r c es i n M ar ch 2 00 7.

Power flow diaGramsJ.1 Guide to the Power flow diagrams

APPENDIX J


J-1

APPENDIX J POWER FLOW DIAGRAMS

T h i s a pp e n d ix pr e s e nt s pow e r f l o w diag rams f or th e f o l l ow i ng c ases:

• F ig u r e J - 1 S u m m e r P e ak 2 0 1 0 ,

• F igure J -2 Summer Va l ley 2010,

• F igure J -3 Winter Peak 2010/11 ,

• F ig u r e J - 4 S u m m e r P e ak 2 0 13 ,

• F igure J -5 Summer Val ley 2013 ,

• F igure J -6 Winter Peak 2013/14,

• F igure J -7 Summer Peak 2016,

• F igure J -8 Summer Va l ley 2016,

• F igure J -9 Winter Peak 2016/17,

N o t e th at s um m e r c as e s i n c l u d e a l l pr o j ec t s e xp ec t e d t o b e com p l et e d b y 1 s t J u l y o f t h e y e ar

s tated and winter cases inc l ude a l l pro jects ex pected by 1 s t December o f the year st at ed. As

s u c h, t he l ay o u t o f t he n e t w o rk i n th e p o w er f l o w d i ag r a ms m a y n o t f e a t u re a l l pr o j ec ts

l is t e d i n A ppen d i x B f or a p ar t i c ul ar yea r a s t h e s e a r e l i s t e d on a y ea r l y bas i s .

J.1 GUIDE TO THE POWER FLOW DIAGRAMS

D i f f e r e n t c ol o u r s r e pr e s ent e ac h o f t h e v ol t ag e l ev e l s :

• 4 00 kV r ed,

• 275 kV (NIE Interconnector ) b lue,

• 220 kV g reen,

• 110 kV b lack.

G enerat i on c onnec t ed at each bus i s show n besi de a symbol , w i th th e g ener at i on

d i s p at ch e d i n M W sh ow n b e n e a t h t h e s y m b ol . E m b e d d ed g e n e r at i on i s s h o w n a t t h e

t r a n s mi s si on b u s t o w hi ch i t i s c o n n e c t e d thr ou g h t he d i st r i b ut i o n s y st e m . T h e E as t – W est

in terconnector is denoted by a symbol . The magni tude of imports o f power on the

i n t er c o n n e cto r i s g i ven ben e a th t h e sym b o l i n M W.

There are two values sh ow n at both ends of each c i rcu i t . Th e value abov e the l ine is the MW

f l ow and the v al ue below th e l i ne i s th e Mv ar f l ow . A posi t iv e v al ue i ndi c at es th at th e

d i r ec t i o n of f l ow i s a w a y f ro m t h e b us ; a n eg at ive va l ue , t o war d s th e b us.

T h e v ol t ag e, i n p er u ni t va l u e , i s d i spl a y e d b el o w e a c h b u s .

134

922

-11

-21

17

2

-18

-2

15

2

-16

18-18

11

4

0 6

-0

16 -12

-86

16

86

-12

-42

42 10

10

-27

33-32

33-32

13 -13

9

-11

-2

11

2

-5

-24

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24

21

-25

25 12

-25

25

-25

-12

25 13

-23

-9

23

9

28 10

-28-33

-9

22-2

2

10

22 -10

-17

17 14

15 5

-15 -6

-21

9

21-9 9

21

16 5

-45

108

4

-107 -6

-44

7-7

3

-6

-24

-4 -1

-5

-7

4

-15

43 2

242 12

-10

-6 -3

24

-61

1

5121

-5

-3

-0

-24

2-2-10

-2

-0

11

-24

-24

-11

18

25-29

2

-6 -22

6 17

-7 -32

13

15

-12

-16

13-12

-13

1-127

-22 22

-26

26

-28

28

-31

31

-2

-24

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24

21

-41

-3

16 -6

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72-7

1

-4 -16

4 16

11

0

-176

179

-12

-29 4

30 -4

9 1

-9

-1

-52 -8

52 10

-35

16

36

-17

-40 3

40 -3

103 -103

18

42

-8

-41

-22

23 -7

-15 7

15

94 -36

-94

3694 -36

-94

-49 -4

49

2

-26

86

-86

-25

86 29

8

-73

33 31

-33

-39

-7

-18

-19

10

-38

-14

-24

-10

24

10

-2

-17

1

-31

-26

32

-49

-7

-23

-8

-21

-5 1312

-12

9

-1

-8

-2

-2

-3

2 1

-31

31

2-1

-30

-4

-8

-149

9 7

-9

-8

-22

-13

14

-95

95

-58

8

59 -5

47 -0

-46

1

11 3

-11 -5

18

-5 -43

32 7

-15

1

-4

-1

4 0

6 18

-6 -20

-17

-36

32

37

-31

50

-5

-49

6

11

-11

6

-20

11

28

-22

24-24

-35

-30

36 24

27

-69

69 14

8-8

-37

15

11

50 -11

-45

11

50

-10

-46 12

46

-3

23 3

-8

-20

-7

28 8

136

-135

-44

34

-50

-37

-195

23

37-3

7

6 6

-0

-3

5

-10

-10

10

10

10 -5

-10 -8

10 -5

-10 -8

-17

17

15

-13

-15

13

2

-18

-2 12

-16

-20

21 20

-20

20 0

-30

30 15

-2

1

2

-2

-2

4

1

6

-0

-0

-0

6

14-15

7 -7

-4

81 13

-79

17

2

-325

5

-5

-5

61

16

-16

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16

1

73

-33

-1

-119

1446

-0

21

-1

24

195

21

27

4

4

-26

-5

33

2

-2-6

8

5

9

-118

10

20

7 29

30

7

9

-11

-22

16

-31

-12

-10

-14

7 -16

-27-3

20

-88

-20

-13 11

17

-1

-8-1

-17

8

6

-7

-13

-10

21 -53

-50

8-9

-58

6

231

-20

10

0

-5

15

13

-26

-34

2

-20

-86 86

-11

-13

151

-242

-71

-12

13

-22

-18

-95

17

43

27

13

17

GWE-6

19

38

36

-3

-27

23

-10

-25

-21

46 28

-30

30 14

-63

-26

63

95 34

108 24

3-1

0

-00 0 0

-0

3

32

4

15 9

-15

-24

-2

-15

-10

15 10

-11

-30

1

-14

-30

-10

-0

-0

-15 15

11

-31 3

31 -3

-15

-11

-26

11

26 -1

-5

-10

5

0

1035

16

-44 24

65

48

-9

27

0

-26

-12

12

22-2

2 -9

MP

-5

13

5

-13

13

-6 5

8080

8 -4

-8

-15

83-8

3

5

-21

13 21

-16

7

16

-7

6

-21

-7

-0

-12

-0

30

-13

37

11

9

-2

-2

-24

7

4

-12

13

0

49

4-3

8

-29

-21

-2

24

3 14

18

-5

25

-230

17

7

0

5

-4

-10

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2

-15

-0

-12

-9

6

3

-3

-6

-7

-27

-46

12

-12

-0

-18

-20

-8

-13

16

3

-17

4

-30

30

13

13

-29

-9

53

-31

-2

LIS

STR

ARV

59

MTH

KER

ARK

13

BOL

ARI

14

-12

1-28

-8

-0

-0

38

9

1 -32

2

0-22

-2

-12

16 -12

-3 -23

51

-16

-5

IKE

13

16

CLW

GOR

2 -5

-51

PLS

DOO

GAL

-32

1

-4

4

6

0

TB

SH

-13

TLK

CF

30

10

-14

-13

RYB

KKY

-13

-4

-1

11 -7

-9

-21

BLK

-518

32

16 -3

3

-23

BIN

DRM

-49

-3

TAW

DFR

-48

-1

48 -0

-5

-29

3

29

-15

24-2

4

-6

-42

42 9

CDU

CSH

-1

-1

34

-5

5

-31

29

0 0

0 0

NEW

-0

TON

CLN

3

-1

21

-4

ATH

-7

4

-2

-9

-11ANR

-11

PRO

-8-2

20

32

17 24 17

0

-24

-15

-16

-9

-9

13

45 34

-11

2

12

MAY

-354

20 RNW

54

22

25

2-2

-6

184 17

-45

-31

-11

DSN

-27

INC

-183KRA

0

CUL

-0

-7

CDU

-5

-20

104

6

30

-9

5

SVN

FIN

2

-32

-2

13

-0

LIM

8

-13

-25

GAE -2

CD

-49

24

245-5

7

-9

CHA

GIL

-3

BEG

ARK

CRA

KLS

PA

MAY

MCE

FIN

FIN

CKM

KTL

MON

GIWAT

BUTBDN

KTN

WHI

OLDBAN

LIB

SH

MP

TBK

BAR

THU

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SRA

AGL

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SLI

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LET

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SOR

CL

GOR

EKN

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6

DAL

10

CUS

TSBDER

KIN

SKL

NAV

95

KLS-8

0

1

BLI

DMY

FAS

-18

272 MW

-14

RAF

TBG

MID -4

1 MW

1 MW

0 MW

274 MW

5 MW

ATE

6

SOM

2 MW

0 MW

12 MW

NW

SHL

PB

GCA

44

-95

WEX

15

-1

COL

BAL

-6

PLA

WOO

-48

-8

LOU

RRU

KUR

INC

GRI

TH

GI

MUL

ISH

-16

2 MW

COR

SBN

31 30 -2

FLA

FLA

12

CDY

COS

LSN

CUL

TIP

LA

CAH

DGN

-6

0 MW

AD

CVW

25

KLN

0

KLN

CSH

4

MOY

AA

-14

DYN

RAT

MAL

-13

13

-5

MTN

MUN

-17

-80

-80

17-1

7 AUG

SK

DRU

ENN

27

DLT

CBR

-2 KRA

KBY

MR

COW

MAC

50

CKN

CLA

CLA

CGL

TRL

OUG

TRI

CLH

IA

CRO

CDU

-86

9

13

GLA

-11

GOL

-13

24

BRYRSY

-22

ATY

BDA

TB

RAF

J-02

-86

24

25

86 88

30 MW

15 MW

0 MW

-87

-20

-19

1 MW

15 MW

0 MW

0 MW

1 MW

0 MW

118 MW

13 MW

0 MW

0 MW0 MW

260 MW

3 MW

21 MW

13 MW

0 MW

3 MW

1 MW

141 MW

2 MW10 MW

137 MW

3 MW

243 MW

2 MW

1 MW93 MW

291 MW

14 MW5 MW

35 MW

6 MW

20 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

75 MW

99 20-1

5

275 MW

14 MW

15 MW

1 MW

195 MW

0 MW

1 MW

0 MW

4 MW

21 MW

4 MW

161 MW

2 MW

0 MW

243 MW

11 MW

5 MW

23 MW

13 MW

16 MW

26 MW17 MW

17 MW0 MW

20 MW

0 MW

13 MW

1 MW

5 MW

57 MW

-99

9 MW

12 MW

0 MW

102 29

-102

-90

-242

-1229

-26

242

-10

MAY

-28

-291

5 -2

-5 2

5 -2

-5 2

10 -5

-10 5

59

291

-36

-290

51290

HN

LOU

HN

TAN

51 19-1

9

13

-51

DSN

MP

MP

MP

WOO

192

10

0-0

-3-10

1

0

BWR

-0

-16

-54

4 313-5 -1

3

-00

2

-13

38

-8

-4

-6-18

-1-2

-38

RIC

-0

-5

1310

NAN

BRI

1

-13

CKM

-0

260

-260

21

100

7

-18

90 -59

0

-63

63 22

17

-187 188

-14

-29

-102

115

-33

-8-100

-113

24

1033 -16

-43

-28

-56

102 28

91

43

-1

-15

1

-34

26

-0

-31

-90

-3

-42

OST

TYN

MAY

3

118-118

SHL

0

-256

PB

293

92-191

-65

-291

-59

OST

Figure J-01 Power Flow Diagram Summer Peak 2010

-2

5

-12

10

7 -9

7

42

15-22

-1522

-0

21

-1

-21

-18

14

18

-14

38-8

-19

34

7

-34

7

-7

-87

4-5

16

-5-16

-0-2

02

1248

-11

-48

132

-15

-2

-32

-20

20

-2

-87

-888

-44

152

44

-152 40-59

-4360

577

-16

-76

-13

-62

11

-7-17

617

-17

617 -4-6

36

25

-53

-2255

-4

-419

3

2-4

568

-2

-67

0-7

-2

7

-8

-20

7

20

19148

-18

-146

41

-123

-42

125

-2

52

-11

-52

50293

-51

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241

-2

-41

-5-44

644

0

-0

-0

0-1-2

12

12-1

2

8

-6

157

10-155

-9

9

-20

20

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-10

16

-15

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8

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40

24

-24

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7

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18

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272

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5

274

8

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241

2

12

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8

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2

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-6

-2

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513

33

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6

-0

0

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-20

20 12

20

20 -21

-20

-1-3

-2

-1

10-1

0

22

-12

CLA

12 -7

7

KEE

64

15

0

-8

-150 -6

150

6

KRA

KUD

-16

12

GGO

AD

GAR

-7

-22

CFM

-17

49ADM

-270

77 8

BRI

-274

14

-10

AD

21

INC

-24

-81

-5-12

4

1-4

CPK

4

WOO

-12

AD

LPT

-0

2758

SNG

10

51

8

-64

-16

DRO

4

BGH

-7

62

4

-3

-88

3

-19

FIN FIN

32

-7-17

717

417-1

7

ATHY T

-3

-41

-7

17-29

-07

-2

-7

5

-2

-5

2

5

-2

-5

25-25

11

4

5 7

-5

-14 14

-2

-14

2

14

-15

15 9

2

-11

14-14

14-14

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-7

10

7

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6

-18

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18

-10

10 12

-10

10

-10

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10 12

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6

18 2

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12

36-3

6

11

36 -11

5-5 3

14 0

-14 -1

-16

-13

1513 -13

15

7 -0

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1 -4

-1 -1

32-3

2

-67

-5

-2

-19

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-1

7

-1

324 -2

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-8

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10

1

-22

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374

14

0

1

-3

8-8-10

44

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15

-3

-3

-15

9

20-5

14

7 -3

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10 -2

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7

6

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5

-7

2-2-1

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14

5

6

-18

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18

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12

13

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-8 -0

8 -0

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14

-47

48

-19

-19 5

20 -6

8 3

-8

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13 9

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4

10

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13 -2

38 -38

10

12

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10 -10

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113

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10

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26

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25 18

12

21

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25

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4

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24

10

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10

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42

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-8

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7

20

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2

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6

18

17

19

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8

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8

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11

6

7

6

14

3 3

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41

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3

18 -4

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6

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2

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9

2

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31

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1 -0

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10 -11

-5

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2

17

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6

10

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1

10

6

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94 -35

-94

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8

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6

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7

7

25 -7

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7

25

-7

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23

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1

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5

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29

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0 -4

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2 -2

0

-9

7

-7

3

7

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0

109

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109 -9

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30

2

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5

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4 2

-7

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3 0

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4 -1

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-8

0

7

6

4

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2

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0

0

6

11-11

10 -10

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77 -19

-75

10

25

-19-4

8

4

-9

22

6

-5

21

22

1

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-116

-7

-73

423

-0

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12

3

-0

36

14

-12

18

1

-3

117

-6

-0-2

-13

-2

5

-3-1

8

3

9

-10

-0

5

-7

5

-13

-16

-4

-39

-6

-3

-7

8 -0

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6

-82

-14

-13 4

26

11

13

-9

3

-7

6

-3

-2

35 -48

-25

-10

-7

25

152

-4

10

-2

-3

-31

13

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PRO

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2

0

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LET

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CL

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CUS

TSBDER

KIN

SKL

NAV

35

KLS-3

0

4

BLI

DMY

FAS

-12

0 MW

1

RAF

TBG

MID -3

1 MW

1 MW

0 MW

98 MW

5 MW

ATE

-13

SOM

2 MW

0 MW

12 MW

NW

SHL

PB

GCA

8

-41

WEX

8

-1

COL

BAL

-7

PLA

WOO

0

-3

LOU

RRU

KUR

INC

GRI

TH

GI

MUL

ISH

1

2 MW

COR

SBN

-6 -6 2

FLA

FLA

18

CDY

COS

LSN

CUL

TIP

LA

CAH

DGN

-2

0 MW

AD

CVW

17

KLN

1

KLN

CSH

-7

MOY

AA

1

DYN

RAT

MAL

-78

-3

MTN

MUN

1

-80

-80

-21 AUG

SK

DRU

ENN

11

DLT

CBR

-19 KRA

KBY

MR

COW

MAC

54

CKN

CLA

CLA

CGL

TRL

OUG

TRI

CLH

IA

CRO

CDU

-26

5

8

GLA

-8

GOL

-8

-7

BRYRSY

-10

ATY

BDA

RAF

J-03

-35

1

1

35 36

30 MW

15 MW

0 MW

-36

-1-0

1 MW

15 MW

0 MW

0 MW

1 MW

0 MW

118 MW

-210 MW

0 MW

0 MW0 MW

257 MW

3 MW

21 MW

13 MW

0 MW

3 MW

1 MW

0 MW

2 MW10 MW

137 MW

3 MW

0 MW

2 MW

1 MW93 MW

0 MW

14 MW5 MW

35 MW

6 MW

20 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

0 MW

53 -24

160 MW

14 MW

15 MW

1 MW

0 MW

0 MW

1 MW

0 MW

4 MW

21 MW

4 MW

161 MW

2 MW

0 MW

0 MW

11 MW

5 MW

23 MW

13 MW

16 MW

26 MW17 MW

17 MW0 MW

20 MW

0 MW

13 MW

1 MW

5 MW

0 MW

-53

9 MW

12 MW

0 MW

55 -45

-55

-89

0

-66

47

0

-29

MAY

-17

-21

-55

0

55 1

-54

0

54 1

-109

2

109 -0

7

21

-7

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HN

LOU

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TAN

44 -25

25

6

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MP

MP

MP

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4

0-0

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0

0

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1 15-2 -5

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2

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18

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4

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RIC

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1

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BRI

1

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CKM

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257

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115

73

6

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90 -32

0

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55 -55

47

45-55

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16

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70

55 -47

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142

30

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27

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-44

OST

TYN

MAY

7

71-71

SHL

0

8-70

PB

21 1734 -64

-21

-7

OST

Figure J-02 Power Flow Diagram Summer Valley 2010

-2

5

-31

8

27 -6

8

-842

20-31

-2032

-4

14

3

-14

-21

28

21

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13-3

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15

1

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6

6-6

3-4

13

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01

1017

-10

-17

14-6

-15

6

-1-3

3

-9

-21

-521

-2674

25

-73 26-27

-2927

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-5-42

-3-31

1

-4-10

310

-10

310 -1-10

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2

-23

-223

8

-16

46

17

-943

-114

-0

-14

8

-16

-9

16

-2

-8

1

8

1027

-19

-27

7

-14

-19

14

-2

13

-11

-13

-1844

-18

-43

-641

6

-41

-912

9

-12

0

0

-0

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12

6-6-1

-13

51

4-51

-9

2-33

-31

-14541

-3

16

8

-53 3

-7

-1

7

1

14-14

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5

-11

9

-14

-6

-0

30

-19

98

3

-84

85

0

00

-42

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-11

-0-1

2

-6

-1

-1

-13

06

13

8

-0

-0

-10

6

0 -3

-20

20 -4

0

20 -1

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-0-3

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-2

10-1

0

22

-11

CLA

12 -4

2

KEE

8

-8

0

1

-52 7

52 -10

KRA

KUD

-4

12

GGO

AD

GAR

-3

-22

CFM

-10

7ADM

0

42 -5

BRI

-98

-0

-3

AD

14

INC

-44

-41

-5-12

2

2-2

CPK

22

WOO

4

AD

LPT

0

1511

SNG

3

14

9

-8

-16

DRO

4

BGH

-3

31

-42

10

13-1

3

-9

-46

FIN FIN

1

-4-12

412

313-1

3

ATHY T

-1

-41

1359

1014

-12

-14

16

8

-16

-7

14

7

-14

22-22

11

4

0 -0

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15 -8

-107

15

107

-8

-19

19 25

15

-34

42-41

42-41

11 -11

6

-24

-6

24

5

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-41

-21

41

24

-34

34 13

-34

34

-34

-11

34 13

-31

-11

32

11

36 12

-36-88

-12

45-4

5

19

45 -19

-40

-26

40 19

27 9

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-19

26

19-26 26

20

30 11

-81

160

-7

-159 9

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18

10-1

0

18

-14

-13

-6 -1

-7

-6

6

-12

38 -3

261 14

-11

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15

-44

-35

5124

10

-7

-6

-44

-11

12-14

-44

0

46

-21

-21

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20

31-47

-2

19 -23

-19

18

33 -32

35

13

-35

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-32

-9

24-2

4

17

-17 17

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27

-29

29

-30

31

4

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42

24

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17

31

-8

-31

52-5

1

19 -2

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18

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-259

265

-5

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15 -1

35 3

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-53

-10

53 11

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21

47

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52 -2

129 -129

20

52

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25 -7

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15

129

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2712

9

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-77 9

77

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99

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99 32

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53 39

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-8

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10

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24

10

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1

26

12-1

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9

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11

12

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1

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38

7-5

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0

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9 5

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14

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142

-77

11

79 -3

66 2

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15 -12

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36

6 -0-1

16 13

19

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6 1

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14 -17

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53

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71

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7

15

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16 -46

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85 22

5-5

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8

6

69 -6

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20

50

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49

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157

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75

37

20

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40-4

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6

20

6

13

4

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7

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4

63 -16

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4

63 -16

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16

15

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14

5

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8 14

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31 19

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2

5

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5

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34

11

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3 -0 -24

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0 0

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5

6

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29

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8 -18

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26

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9

5

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41 -61

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4

209

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0

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2-1

3

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161

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29

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14

50

37

14

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GWE-14

21

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84 30

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142

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0-0 -0 0

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52 -44

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31 -3

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10

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842

16

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80

21

3

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54

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28

6

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12

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2 -9

MP

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5

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12 -1

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118

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50 7

18

24

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58

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6

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6

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7

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1

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37

16

15

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98

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LIS

STR

ARV

65

MTH

KER

ARK

13

BOL

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5

1

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0

0

74

10

1 -3

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3

1-2-8

8

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18 -11

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79

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IKE

14

32

CLW

GOR

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-79

PLS

DOO

GAL

-44

2

-4

7

4

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TB

SH

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TLK

CF

28

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RYB

KKY

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1

8 -13

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BLK

0-28

33

14 0

2

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BIN

DRM

-68

3

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TAW

DFR

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16

17 -18

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2

20

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27-2

7

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41 10

CDU

CSH

20

7

61

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3

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31

0 0

0 0

NEW

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TON

CLN

-6

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21

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ATH

9

-5

6

-8

-26

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-46

PRO

-733

15

31

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10 15 11

2

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20

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19

29 21

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5

32

ATY

MAY

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27 RNW

44

40

25

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176 13

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DSN

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INC

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0

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RAF

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CDU

-6

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94

12

33

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SVN

FIN

44

244

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8

LIM

8

0

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2

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CHA

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16

CUS

TSBDER

KIN

SKL

NAV

161

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0

12

-7

BLI

DMY

FAS

-15

389 MW

-18

RAF

TBG

MID

LWD

10 MW

14 MW

-2

1 MW

1 MW

0 MW

196 MW

5 MW

ATE

11

SOM

2 MW

0 MW

12 MW

NW

SHL

PB

GCA

206

-142

WEX

27

1

COL

BAL

-12

PLA

WOO

-54

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LOU

RRU

KUR

INC

GRI

TH

GI

MUL

ISH

-14

2 MW

COR

SBN

30

29

-3

FLA

FLA

24

CDY

COS

LSN

CUL

TIP

LA

CAH

DGN

14

BRY

0 MW

RSY

AD

CVW

20

KLN

-17

KLN

CSH

-1

MOY

AA

-16

DYN

RAT

MAL

-13

13

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MTN

MUN

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-80

8-9 AUG

SK

DRU

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34

DLT

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MR

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MAC

52

CKN

CLA

CLA

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TRL

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IA

CRO

CDU

-99

17

13

GLA

-12

GOL

-13

14

J-04

-113

42

44

113

116

30 MW

15 MW

0 MW

-115

-35

-34

1 MW

15 MW

9 MW

0 MW

0 MW

1 MW

34 MW

12 MW

0 MW

18 MW

120 MW

0 MW0 MW

300 MW

3 MW

21 MW

13 MW

0 MW

3 MW

1 MW

414 MW

3 MW

2 MW10 MW

137 MW

3 MW

261 MW

2 MW

1 MW93 MW

276 MW

14 MW5 MW

35 MW

6 MW

20 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

120 MW

136 20

-136

-10

295 MW

14 MW

15 MW

1 MW

295 MW

0 MW

1 MW

20 MW

89 MW

21 MW

4 MW

161 MW

2 MW

8 MW

261 MW

11 MW

5 MW

3 MW

26 MW

13 MW

16 MW

26 MW17 MW

17 MW0 MW

35 MW

19 MW

13 MW

1 MW

5 MW

0 MW

109 30

-109

-85

-261

-1433

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261

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MAY

-25

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2

31 -2

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2

31 -2

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5

63 -4

59

309

-33

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HN

LOU

HN

TAN

57 22-2

2

15

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DSN

MP

MP

MP

WOO

204

13

0-0

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7

0

BWR

-0

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-44

4 313-5 -1

3

42 -42

19

13 -13

4-00

2

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5 5

-3

38

-4

-2

-9-24

-1-2

-10-25

-38

RIC

-0

-5

13

1

NEN

LWD

NAN

BRI

1

HTS

-13

CKM

-0

300

-299

-28

92

20

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85 -45

120

4-4 16

-5

-166 167

7

-30

-109

122

-2

-21

-91

-119

26

152 -23

-65

-29

-82

109 30

61

65

7

-19

17

15

35

-120

-41

-61

-36

-36

OST

TYN

MAY

-3

206-206

SHL

32

-783

PB

312

94-203

-67

-309

-59

OST

Figure J-03 Power Flow Diagram Winter Peak 2010/11

-2

5

-4 10

-1 -10

18-41

-18

42

-5

25

4

-25

-5

-83

-584

-3167

29

-67 83-133

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133

032

-12

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-8-16

6

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1330

-30

1330 -5-14

414

30

-68

-2572

-3-12

212-1

112

-1

0-7

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6

-68

1

-18

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18

-11

-25

11

25

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-2

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49

-159

-42

162

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90

-6-89

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6

4

58318

-52

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541

-5

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446

0

0

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12

13-1

1

53

1

185

9-182

-175 -5

13

-175

-9

12-33

34

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16

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7

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178

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153

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3

13

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21

-7

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7

20

119

5

13 4

19

23 8

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47

-23

23

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55

2

20

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RAF

-1

-10

6

-23

-2

CDK

-17

91

17

-3

3

0

0

-41

-11

-388 -24

-20

20 -0

32

35 -32

-35

-1-3

-3

2

10-1

0

22

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CLA

12 -1

39

KEE

81

29

-0

175

-53

-132 -14

132

14

KRA

8

5

KNR

KUD

-30

12

GGO

-13

AD

CBG

GAR

-13

-22

CFM

-23

24ADM

-385

175

5

139 21

-16

BRI

-195

21

-12

AD

-29

-42

INC

-1

-26

-5-12

-9

12

-2-12 CPK

-12

WOO

-0

AD

LPT

-0

-22

35

SNG

10

54

8

-81

-16

DRO

4

BGH

-13

16

7

-2

-12

12

-1

-12

BRY

FIN FIN

-20

95

62

-188

713

53

-7

-3

15

-3

-16

2

14

-2

-14

-22

11

4

0 6

-0

3 -0

-69

3

69

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-66

67 22

6

-28

35-35

35-35

-7 7

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0

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11

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-33

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33

21

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37 13

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37

-37

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37 13

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25

10

30 11

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9

16

49 -16

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21

20-21 21

20

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75 -1

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6

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224 11

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5100

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5

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8

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23

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79 34

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5

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26

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59

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50

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79

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STR

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30

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KER

ARK

13

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12

0

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1

0

0

47

13

3 -5-7

SRA

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1-2-5

5

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20 -11

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144

0

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IKE

38

13

CLW

GOR

26

23 -23

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PLS

DOO

GAL

-21

1

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3

0

TB

SH

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TLK

CF

15

6

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RYB

KKY

-11

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2

12 -7

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-13

BLK

-2-1

37

12 -2

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-7

BIN

DRM

-30

-6

-39

TAW

DFR

-29

11

29 -13

-17

-9

15

9

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25-2

5

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43 10

CDU

CSH

4

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18

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0 0

0 0

NEW

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TON

CLN

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111

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2

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TSBDER

KIN

SKL

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47

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0

11

1

BLI

DMY

FAS

18

-14

370 MW

-21

RAF

TBG

MID

LWD

16 MW

14 MW

0

1 MW

1 MW

0 MW

372 MW

5 MW

ATE

5

SOM

TUR

2 MW

0 MW

22 MW

12 MW

NW

SHL

PB

GCA

76

-70

FAS T

WEX

16

-2

GLACOL

BAL

-17

PLA

WOO

-24

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LOU

-90

RRU

KUR

INC

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TH

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-12

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COR

SBN

18

17

3

FLA

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20

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CGL

TRL

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TRI

CLH

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CRO

CDU

-65

19

6

13

J-05

-91

27

28

91 93

30 MW

15 MW

0 MW

-93

-23

-22

1 MW

15 MW

224 MW

9 MW

0 MW

0 MW

1 MW

0 MW

12 MW

118 MW

60 MW

0 MW

0 MW0 MW

310 MW

3 MW

260 MW

21 MW

13 MW

0 MW

3 MW

1 MW

0 MW

0 MW

3 MW

3 MW10 MW

137 MW

3 MW

224 MW

2 MW

1 MW93 MW

0 MW

14 MW5 MW

35 MW

6 MW

20 MW

5 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

0 MW

79 -8

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11

274 MW

14 MW

15 MW

1 MW

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0 MW

0 MW

4 MW

0 MW31 MW

9 MW

3 MW

21 MW

4 MW

161 MW

1 MW

2 MW

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224 MW

11 MW

5 MW

3 MW

26 MW

13 MW

16 MW

26 MW17 MW

17 MW0 MW

35 MW

0 MW

13 MW

-77 8

77

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45

94

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6

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210

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26 -65

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RIC

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NEN

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BRI

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CKM

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309

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123

119

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87 -40

0

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1.0000

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15-28

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18

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11

9

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4

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29

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3 3

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RAF

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411 MW

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NW

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270 MW

9 MW

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1 MW

34 MW

12 MW

118 MW

58 MW

0 MW

0 MW0 MW

380 MW

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350 MW

21 MW

13 MW

0 MW

3 MW

1 MW

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188 MW

3 MW

3 MW10 MW

137 MW

3 MW

270 MW

2 MW

1 MW93 MW

150 MW

14 MW5 MW

35 MW

6 MW

20 MW

5 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

0 MW

115 22

-115

-15

403 MW

14 MW

15 MW

1 MW

274 MW

4 MW

48 MW

4 MW

20 MW31 MW

9 MW

89 MW

21 MW

4 MW

161 MW

1 MW

2 MW

8 MW

270 MW

11 MW

5 MW

3 MW

26 MW

13 MW

16 MW

26 MW17 MW

17 MW0 MW

35 MW

19 MW

13 MW

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INC

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19

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RAF

TBG

MID

LWD

16 MW

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2

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5 MW

ATE

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NW

SHL

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FAS T

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PLA

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3

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32

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30 MW

15 MW

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233 MW

9 MW

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1 MW

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12 MW

118 MW

20 MW

0 MW

0 MW0 MW

370 MW

3 MW

370 MW

21 MW

13 MW

0 MW

3 MW

1 MW

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3 MW

3 MW10 MW

137 MW

3 MW

233 MW

2 MW

1 MW93 MW

0 MW

14 MW5 MW

35 MW

6 MW

20 MW

5 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

0 MW

85 -4

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7

344 MW

14 MW

15 MW

1 MW

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0 MW

0 MW

4 MW

0 MW31 MW

33 MW

3 MW

21 MW

4 MW

161 MW

1 MW

2 MW

0 MW

0 MW

233 MW

11 MW

5 MW

3 MW

26 MW

13 MW

16 MW

26 MW17 MW

17 MW0 MW

35 MW

30 MW

27 MW

0 MW

13 MW

-77 17

77

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NEN

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OST

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7

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AD

LPT

0

2

9

321

SNG

-49

ONH

-2-17

2

5

9

KNR

-41

41

CKN

GRO

-33

66

5

-66

-16

DRO

4

7

27

10-27

-10

7

-3

TOE

BGH

0 MW

1.0000

15 7

-15 -6

1.0000

-5

256

40

-351

817

1-2

-3

2

18

-4

-18

3

16

-3

-16

-22

11

4

0 6

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12 -8

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12

90

-8

-75

75 25

12

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47-47

47-47

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9

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13

6

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-19

15

19

-43

43 11

-44

44

-44

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36

13

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78-7

8

17

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17 3

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17

25-17 17

25

32 13

-36

97 15

-97

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16

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1

7

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-22

11

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163 42

-42

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1

17

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9 16

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41

8

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29

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24

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5

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15

19

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138

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62 12

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40

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46

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1816

7

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5 39

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10

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33

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9

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0

11

13

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5-4

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103

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10

76 -3

59 4

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22

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8

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40 -26

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37

55

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58

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3

3

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30

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60

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96 31

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29

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27

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114 6

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4 5

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10

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12

9

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6

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14

6

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5 15

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7

34

2

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0 1 -66

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65 14

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11

2

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23

8

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19

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97

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935

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37

37

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5

12

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7

12

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33

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18

22

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4

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19

9

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0

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1

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74 -54

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25

214

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5

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6

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106

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-78

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-74

12

49

26

8

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GWE-15

9

35

18

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34

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26 -26

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63 21

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31 12

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64

103

41

110 22

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12

69

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0-0 -0 -0

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41

2

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56 -34

0

20

9

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3

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15

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31 -3

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13

3

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11

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423

21

-54 35

85

26

12

-26

52

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23

10

-23

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12

22-2

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MP

-5

18

6

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18

-7 6

8080

14 0

-14

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91-9

1

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32 2

-5

18

5

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6

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0

30

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36

11

6

5

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12

17

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14

0

87

6-59

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19

6 15

17

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12

8

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5

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5

7

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18

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0

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10

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50

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31

18

7

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-7

52

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LIS

STR

ARV

48

GOL

MTH

KER

ARK

11

BOL

ARI

-3

0

-9

-12

-30

-8

78

6

-6980

9

2 -3

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SRA

2

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7

-823 -82 -17

75

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1

IKE

6

13

36

CLW

GOR

21

11 -13

-74

PLS

DOO

GAL

-39

2

-4

19

2

-20

TB

SH

-33

TLK

CF

16

1

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RYB

KKY

-11

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-7

-22

BLK

-25

37

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4

-5

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11 4

BIN

DRM

-48

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-56

TAW

DFR

-42

9

42 -11

-16

-22

14

23

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30-3

0

-9

-44

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44 11

CDU

CSH

25

9

41

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4

-36

25

-15

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0 0

NEW

0

TON

CLN

-10

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21

1

ATH

4

-7

5

4

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-11ANR

-11

PRO

-923

11

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9

9 17 10

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66

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14

32 19

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17

38

ATY

MAY

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8 RNW

55

30

21

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283 30

-32

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15

-16

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DSN

10

INC

-282KRA

0

28

CUL

-0

RAF

5

CDU

-7

-13

107

352

16

36

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7

SVN

FIN

-34

CFM

-18

2-1

818

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8

LIM

8

6

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GAE -2

CD

6

25

197-7

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-9

CHA

GIL

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TB

BEG

ARK

CRA

KLS

PA

BDA

MAY

MCE

FIN

FIN

BOG

CKM

KTL

MON

GIWAT

BUTBDN

KTN

WHI

OLDBAN

LIB

SH

MP

TBK

BAR

THU

AHA

SRA

AGL

CAM

BK

CUN

SLI

BUN

MEE

LET

KTY

SOR

CL

GOR

EKN

LOU

MLN

DDK

DRY

-10

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GLE

8

DAL

12

CUS

TSBDER

KIN

SKL

NAV

74

KLS17

0

15

-9

BLI

DMY

FAS

34

-17

418 MW

-16

RAF

TBG

MID

LWD

16 MW

14 MW

8

1 MW

1 MW

0 MW

421 MW

5 MW

ATE

5

SOM

TUR

2 MW

0 MW

22 MW

12 MW

NW

SHL

PB

GCA

179

-103

FAS T

WEX

30

1

GLACOL

BAL

-16

PLA

WOO

-51

-17

LOU

-57

RRU

KUR

INC

GRI

TH

GI

MUL

ISH

14

2 MW

COR

SBN

24

23

-2

FLA

FLA

30

CDY

COS

LSN

LSE

CUL

TIP

LA

CAH

DGN

-4

BRY

0 MW

RSY

AD

CVW

14

KLN

-49

KLN

CSH

-4

MOY

AA

-18

DYN

BCM

RAT

MAL

-13

13

-5 -13

MTN

MUN

-13

-80

-80

12-1

3 AUG

SK

DRU

ENN

39

DLT

CBR

25 KRA

KBY

MR

COW

MAC

-6

CKN

CLA

CLA

CGL

TRL

OUG

TRI

CLH

IA

CRO

CDU

-96

22

2

J-10

-128

53

54

128

130

30 MW

15 MW

0 MW

-130

-43

-42

1 MW

15 MW

242 MW

9 MW

0 MW

0 MW

1 MW

34 MW

12 MW

118 MW

52 MW

0 MW

0 MW0 MW

380 MW

3 MW

380 MW

21 MW

13 MW

0 MW

3 MW

1 MW

36 MW

451 MW

3 MW

3 MW10 MW

137 MW

3 MW

242 MW

2 MW

1 MW93 MW

-4 MW

14 MW5 MW

35 MW

6 MW

20 MW

5 MW

12 MW

16 MW

3 MW

2 MW

15 MW

4 MW

2 MW

0 MW

0 MW

118 26

-118

-19

393 MW

14 MW

15 MW

1 MW

343 MW

4 MW

68 MW

4 MW

20 MW31 MW

33 MW

89 MW

21 MW

4 MW

161 MW

1 MW

2 MW

8 MW

0 MW

242 MW

11 MW

5 MW

3 MW

26 MW

13 MW

16 MW

26 MW17 MW

17 MW16 MW

35 MW

30 MW

27 MW

19 MW

13 MW

-78 8

78

-82

38

95

-35

-242

-5168

-18

-22

-112113

-16

-6

18

242

9

-21

MAY

-75

-309

45 3

-45 -2

45 3

-45 -2

90 5

-90 -4

111

309

-84

-276

97277

HN

15

MCV

LOU

HN

-95

TAN

142 0

-0

-2

-142

DSN

MP

MP

MP

WOO

343

14

0-0

-10

-14

9

0

BWR

-0

-6

7

-4

13

-13

-19

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12

-21

-55

4 313-5 -1

3

71 -71

18

46 -45

9-00

2

-6 -6

6 6

14

26

-79

1

41 -66

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-27

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-14-23

-25

-7

RIC

-0

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13

-16

-9

NEN

LWD

NAN

BRI

1

HTS

-13

CKM

-0

379

-379

-11

147

16

-21

82 -48

-0

98-9

8 44

4

-73 73

-8

-878

119

-66

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-147

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31

1666 -7

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64

-34

1

-64

-78 6

15

12

-9

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6

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47

0

-55

-15

-3

-63

OST

TYN

MAY

2

152-152PB

SHL

0

263

41-341

-35

MCV

-261

-14

OST


-2

5

4 10

-9 -9

-15 15

-6 5

TIV

-28

-75

3275

-25

35

26-35

7

-69

-569

-0

-0

0

0

-13

15

-1-2

12

16-1

6

-3

-0

211

17-207

0

-0

7-41

-6

-7-1

1

-20

1033 1033

-10

2066

-20

-66

-30

-15

30

-15

-33

32

9

78 -78

15

-62

6

4

-0

-50

-0-0

-00

-0

-00

656

-9

0

-10

-12

12-20

-13

26

-9788

20

53-4

8

73

10

-3

243

17

-242

-41

51

36

-21

0-1

0-1

620

3

-243

-19

-12

35-3

5

-1

-35

37

157

-156

50

-117

-43

119

32194

-32

-194

194

-32

-377

-5

49

6

-49

9

-35

-9

35

4167

-44

-67219

-8

-6061

2

-81862334

-22

-34

3172

87-253

-83

254

-28

3275

-34

15 1634 1-22

-10

22

16

-3876

37-76

-52 2

-30

-8-7

629629

2

-3

234

36

-233

19

-8-19

6

-42

-4

42

-16

16

-12

29-27

74

12-24

-62

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16

-37

-18

418

24418

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131

12

11

290-92

92

-56

-51

57 16

-81292

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1419

-19

2

-56

57

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24-102

-327

3

-27

18

-18

18-18

-19

18

-14

-14

914

3

13

-92

26

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36

15

-8

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8

23

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33

-11

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4

29

-114

-4-14

7

-8

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92

52

15 5

-5

15 7

-15

30

-15

15

-3

-6

14

-12

41

62

6

-73

22

-92

-35

8

-20

RAF

-1

-8

-33

8 2

-8 -8

6

-15

-46

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102

CDK

-38

-19

18

-97

-277

80277

82

818

38

-8

-0

-0

-289

-39

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-15

0 0

-0

-418 -24

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20 -1

25

35 -25

-35

-1

-19

-82

8

-3 -3

-3

-15

-34

3

-75-2

-194

32

22

-135

MUI

19

-12

KKM

RAL

-379

-6

-51

33 -42

10-1

0

-79

22

35

20

-35

-2

-27

20

-3

TRI

27 42

-22

22

16

42

CLA

-73

KKM

-32

CDL

243

12 -7

7

-31

KEE

KPG

-0

41

20KNR

-20

12

0

377

-2-2

0

3

-214 -16

215

21

KRA

7

MP

KPG

BRY

-0

KNR

KUD

-28

12

FNT

FIN FIN

-29

-7

GGO

-15

AD

SAL

CBG

GAR

BY

-26

-41

-22

-11

GLE

3

-55

-22

CFM

10

-4

-16

12

MRY

-2

LSE

NO

ADM

-88

-413

-66

66-3

3

20

-10

77 18

CKM COU

GRO

BVK

KNR

-15

BRI

-131

-0

21

-18

CHE

BVK

-22

BGT

AD

KCR

BVK

383

-6

-82

-24

-30

2482

BGF

BGF

-61

-86

INC

-2

-72

-5-12

-8-29

46 15 14

-3-14

-15

CPK

34

-20

WOO

7

-73

-15

73 19

FNT

31

1

LSE

AD

LPT

0

-18

-40

-12

24

SNG

-34

ONH

13-15

10

38

8

KNR

-41

41

CKN

GRO

-33

66

-17

-66

-16

DRO

-5

-19

-20

27

26-27

-26

-19

18

TOE

BGH

1.0000

1.0000

400 MW

siZe a3 GeoGraPhical maPs

APPENDIX K


K-1

APPENDIX K SIZE A3 GEOGRAPHICAL MAPS

Appendix K conta ins geograph ica l maps of t h e g r i d i n A 3 f o r ma t . M a p s ar e pr e s e n t e d

i l l ust rat i ng th e g r i d as i t ex i s t s at the begi nning Ju ly of 2009 and as p lanned at the end of

2016.

NORTHERNIRELAND

NORTHERNIRELAND





Wind Generation









COBH

CORK AREA

CARRICKMINESKILTEEL

COOKSTOWN

MILLTOWN

HAROLDSCROSS

RYEBROOK

FINGLAS

INCHICORE

MACETOWN

BLACKROCK

GRIFFINRATH

MAYNOOTH


CITYWEST

CABRA

GRANGECASTLE

HUNTSTOWN

KILMORECOLLEGE

PARK

NANGOR

WOODLAND

GLASMORE

CORDUFF

GRANGE

NORTH WALL

SHELLYBANKS

IRISHTOWN

ARTANE

TANEY

Figure K - 1

RINGSEND

POTTERYROAD

CENTRALPARK

PELLETSTOWN

DARDISTOWN

CROMCASTLE

FRANCIS ST.

NORTH QUAYS

MISERY HILLPOOLBEG

KILTOY


BINBANE

TO STRABANE

GOLAGH

LETTERKENNY

DRUMKEEN

MEENTYCAT

SORNEHILL

TRILLICK

DRYBRIDGE

LISDRUM

LOUTH

DUNDALK

MEATHHILL

MULLAGHARLIN

NAVAN

275kV

TO TANDRAGEE

SLIGO

TAWNAGHMORE

MOY

CASTLEBAR

RICHMOND

CARRICK-ON-

SHANNON

BELLACORICK

TO ENNISKILLEN

GILRA

GORTAWEE

ARIGNA

TONROE

CORRACLASSYCUNGHILL

CORDERRY

SRANANAGH

FLAGFORD

SHANKILL

ARVA

RATRUSSAN

ENNIS

DALLOW

PORTLAOISE

CRANE

CARLOW

KILKENNY

THURLES

CAHIRDOON

ANNER

BALLYDINE

MALLOW

CHARLEVILLE

RATHKEALE

TARBERT

BUTLERSTOWN

DUNGARVAN

BLAKE

TULLABRACK

MUNGRETMONETEEN

FASSAROE

POLLAPHUCA

IKERRIN

LISHEEN

OUGHTRAGH

TRALEE

DUNFIRTH

KILLOTERAN

KILLONAN

RINAWADE

STRATFORDBALLYBEG

TIPPERARY

GLENLARA

ATHY

PROSPECT

MONREAD

TRIEN

DRUMLINE

AHANE

ARDNACRUSHA

LIMERICK

CASTLEFARM

SEALROCK

WATERFORD

TYNAGH

CLAHANE

DERRYBRIEN

AGANNYGAL

AUGHINISH

BOOLTIAGH

WEXFORD

KILTEEL

BALLYWATER

GREAT ISLAND

CULLENAGH

TURLOUGHHILL

MAYNOOTH

INCHICORE

CARRICKMINES

SEEDUBLINAREA

NORTH WALL

POOLBEGSHELLYBANKS

IRISHTOWN

OLDSTREET

FINGLAS

DUNSTOWNBARODA

NEWBRIDGE

HUNTSTOWN

MONEYPOINT

KELLIS

ARKLOW

PLATIN

KNOCKUMBER

GORMAN

BALTRASNA

GLASMORE

CORDUFF

WOODLAND

ATHLONE

CASHLA

GALWAY

LANESBORO

THORNSBERRY

CLOON

SOMERSET

CUSHALING

DALTON

DERRYIRON

SHANNONBRIDGE

KINNEGAD

MULLINGAR

BANDON

DUNMANWAY

MACROOM

BRINNY

KNOCKRAHA

KILBARRY

RAFFEEN

AGHADA

MARINA


TRABEG

BALLYLICKEY

CLONKEEN

COOMAGEARLAHY

GARROW

GLANLEEINNISCARRA

SEECORKAREA

CLASHAVOON


LOUGHMAHON

CORKHARBOUR

AGHADA

WHITEGATE

MIDLETON

KNOCKRAHA

OLDCOURT

CASTLEVIEW

COW CROSS

LONGPOINT

BARNAHELYRAFFEEN

RINGASKIDDY

DUBLIN AREA

KILBARRY

MARINA

LIBERTYSTREET

TRABEGCITYCORK

SHELTONABBEY

NORTHERNIRELAND

NORTHERNIRELAND





Wind Generation









COBH

CORK AREA

CARRICKMINESKILTEEL

COOKSTOWN

MILLTOWN

HAROLDSCROSS

RYEBROOK

FINGLAS

INCHICORE

MACETOWN

BLACKROCK

GRIFFINRATH

MAYNOOTH


CITYWEST

CABRA

GRANGECASTLE

HUNTSTOWN

KILMORECOLLEGE

PARK

NANGOR

WOODLAND

GLASMORE

CORDUFF

GRANGE

NORTH WALL

SHELLYBANKS

IRISHTOWN

ARTANE

TANEY

Figure I - 1

RINGSEND

POTTERYROAD

CENTRALPARK

PELLETSTOWN

KILMAHUD

FINNSTOWNADAMSTOWN

BALGRIFFINDARDISTOWN

POPPINTREE

CROMCASTLE

CHERRYWOOD

HEUSTON SQUARE FRANCIS ST.

NORTH QUAYS

TRINITY

MISERY HILLPOOLBEG

KILTOY


BINBANE

TO STRABANE

GOLAGH

LETTERKENNY

DRUMKEEN

MEENTYCAT

TIEVEBRACK

BUNBEG

SORNEHILL

TRILLICK

DRYBRIDGE

LISDRUM

LOUTH

DUNDALK

MEATHHILL

MULLAGHARLIN

NAVAN

275kV

TO TANDRAGEE

TO TURLEENAN

MID CAVAN

SLIGO

TAWNAGHMORE

MOY

CASTLEBAR

RICHMOND

CARRICK-ON-

SHANNON

BELLACORICK

TO ENNISKILLEN

GILRA

GORTAWEE

ARIGNA

TONROE

CORRACLASSYCUNGHILL

CORDERRY

SRANANAGH

FLAGFORD

CARROWBEG

GARVAGH

GLENREE

SHANKILL

ARVA

RATRUSSAN

ENNIS

DALLOW

PORTLAOISE

CRANE

CARLOW

KILKENNY

THURLES

CAHIRDOON

ANNER

BALLYDINE

MALLOW

CHARLEVILLE

RATHKEALE

TARBERT

BUTLERSTOWN

DUNGARVAN

BLAKE

TULLABRACK

MUNGRETMONETEEN

FASSAROE

POLLAPHUCA

IKERRIN

LISHEEN

OUGHTRAGH

TRALEE

DUNFIRTH

KILLOTERAN

KILLONAN

RINAWADE

STRATFORDBALLYBEG

TIPPERARY

GLENLARA

BANOGE

ATHY

PROSPECT

NENAGH

MONREAD

TRIEN

BALLYCUMMIN

DRUMLINE

AHANE

ARDNACRUSHA

LIMERICK

CASTLEFARM

SEALROCK

WATERFORD

TYNAGH

BALLYRAGGET

CAUTEEN

CASTLEDOCKRILL

CHERRYWOOD

SINGLAND

ATHEA

CLAHANE

DERRYBRIEN

AGANNYGAL

AUGHINISH

BOOLTIAGH

WEXFORD

KILTEEL

BALLYWATER

GREAT ISLAND

CULLENAGH

TURLOUGHHILL

BALGRIFFIN

MAYNOOTH

INCHICORE

CARRICKMINES

SEEDUBLINAREA

NORTH WALL

POOLBEGSHELLYBANKS

IRISHTOWN

OLDSTREET

FINGLAS

DUNSTOWN

FINNSTOWN

BARODANEWBRIDGE

HUNTSTOWN

MONEYPOINT

KELLIS

ARKLOW

LODGEWOOD

LAOIS

PLATIN

KNOCKUMBER

STEVENSTOWN

GORMAN

BALTRASNA

GLASMORE

CORDUFF

WOODLAND

ATHLONE

CASHLA

GALWAY

LANESBORO

THORNSBERRY

CLOON

SOMERSET

CUSHALING

DALTON

SCREEB

SALTHILL

DERRYIRON

SHANNONBRIDGE

KINNEGAD

MULLINGAR

BANDON

DUNMANWAY

MACROOM

BRINNY

KNOCKRAHA

KILBARRY

RAFFEEN

AGHADA

MARINA


TRABEG

BALLYLICKEY

CLONKEEN

COOMAGEARLAHY

GARROW

GLANLEE

GLANAGOW

INNISCARRA

SEECORKAREA

CLASHAVOON


LOUGHMAHON

CORKHARBOUR

AGHADA

WHITEGATE

MIDLETON

KNOCKRAHA

OLDCOURT

CASTLEVIEW

COW CROSS

LONGPOINT

GLANAGOW

BARNAHELYRAFFEEN

RINGASKIDDY

DUBLIN AREA

MUINGNAMINNANE

KNOCKANURE

KISHKEAM

CORDAL

KNOCKACUMMER

KNOCKNAGASHEL

BALLYVOUSKILL

BOGGERAGH

KILPADDOGERALAPPANE

BRACKLONE

NORE

HARTNETT S’SCROSS

KEELDERRY

DROMADA

KILBARRY

MARINA

LIBERTYSTREET

TRABEGCITYCORK

As at December 2016

Figure K - 2

EASTWEST HVDC INTERCONNECTOR

MULREAVY

SHELTONABBEY

BALLAKELLY

The Oval,

160 Shelbourne Road,

Ballsbridge,

Dublin 4.

Telephone +353 (0)1 677 1700

Fax +353 (0)1 661 5375

e-mail [email protected]

www.eirgrid.com

eirgrid transmission forecast statement 20102016

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