southern regional power committee -...

भारत सरकार

GOVERNMENT OF INDIA

विद्युत मंत्रालय

MINISTRY OF POWER

कें द्रीय विद्युत प्राविकरण

CENTRAL ELECTRICITY AUTHORITY

दविण िेत्रीय विदु्यत सवमवत

SOUTHERN REGIONAL POWER COMMITTEE

तकनीकी समितत की छब्बीसवीीं

एवीं द क्षे वव स की सत्ताईसवीीं

बैठकों की कार्यसूची

AGENDA NOTES FOR

26TH MEETING OF TCC

& 27TH MEETING OF SRPC

बेंगलूरु BENGALURU

Agenda Notes for the 26h Meeting of TCC & 27th Meeting of SRPC 1 of 47

CONTENTS

1. CONFIRMATION OF THE MINUTES OF 25th

MEETING OF TCC .................................... 2


MEETING OF SRPC .................................. 2

3. UPCOMING TRANSMISSION SYSTEM ............................................................................... 2

4. TRANSMISSION LINES APPROVED IN 38th

MEETING OF SCPSPSR .......................... 21

5. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE& UMPP ............................ 21

6. NEW PROJECTS OF STATE SECTOR & IPP ..................................................................... 26

7. PAYMENT OF WHEELING CHARGES .............................................................................. 27

8. RESERVE SHUT DOWN (RSD) ........................................................................................... 27

9. EMERGENCY RESTORATION SYSTEM (ERS) ............................................................... 28

10. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR ...................... 29

11. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION ....................................... 31

12. REVIEW OF PERFORMANCE OF ULDC SCHEME ......................................................... 39

13. TRIPPING DETAILS/ DETAILS OF PENDING REMEDIAL MEASURES DISCUSSED

AND FINALIZED IN PCC .................................................................................................... 40

14 S3 REGION TO BE FORMED BY BIFURCATING S2 AND ATC TO BE CALCULATED

FOR S2-S3 REGION BY FOLLOWING THE N-1 CONDITION IN 400 kV UDUMALPET

– PALAKKAD D/C LINES.................................................................................................... 40

15. ITEMS DISCUSSED IN THE MEETING OF COMMERCIAL SUB COMMITTEE ......... 41

16. REIMBURSEMENT OF SRPC EXPENDITURE ................................................................. 41

A FOR INFORMATION OF TCC/ SRPC ................................................................................. 42

1. GRID OPERATION ............................................................................................................... 42

2. ACCOUNTING OF COASTAL ENERGEN INJECTION / DRAWAL ................................ 45

3. INSTALLATION OF SEMs ON BOTH ENDS ( CHARGING CLEARENCE FOR NEW

TRANSMISSION ELEMENTS). ........................................................................................... 46

4. AMR IMPLEMENTATION IN SOUTHERN REGION ....................................................... 47

B ANY OTHER ITEM WITH THE PERMISSION OF THE CHAIR ...................................... 47

C DATE & VENUE OF THE NEXT TCC / SRPC MEETING ................................................ 47



BENGALURU

AGENDA NOTES FOR THE 26th

MEETING OF TCC & 27th

MEETING

OF SRPC TO BE HELD AT HYDERABAD ON 11th

& 12th

MAY 2015


MEETING OF TCC

The Minutes of the 25th

Meeting of Technical Coordination Committee of SRPC held

on 19th

December 2014 at Vishakhapatnam may kindly be confirmed.


MEETING OF SRPC

The Minutes of the 26th

Meeting of Southern Regional Power Committee held on 20th

December 2014 at Vishakhapatnam may kindly be confirmed.

3. UPCOMING TRANSMISSION SYSTEM

3.1 First Meeting of the Task Force on issues pertaining to LGB and Transmission Constraints

was conducted on 19th

March 2015 in SRPC, Bengaluru. Record Notes of the Meeting is

available at http://www.srpc.kar.nic.in/website/2014/meetings/special/m1tfm19-3-15.pdf. In

that Meeting, the following had been agreed:

Data in respect of annual peak demand, ISTS drawl requirement etc. would be

validated and feedback furnished to planners.

Firmed up generation was only needed to be considered. Progress with regard to

important project milestones was needed to be provided.

Spatial load projections was to be forecasted for proper assessment of Intra-state

and ISTS requirements.

Intra-State network needed to be firmed up in coordination with CEA/CTU

(STU needed to coordinate with Intra-State utilities also)

3.2 Pending transmission elements in WR and SR for proper utilization of 765 kV Raichur-

Sholapur line (Out of planned 18 elements)

Sl.

No

Name of

Transmission

Element

Exe.

Agency

Sch.

CoD Expected

date

Remarks

1 Sholapur-Pune

765 kV S/C

PGCIL Oct.20

14

Commissioned on 02.03.2015

2 Pune 765/400

kV S/S

PGCIL Oct.

2014

Mar-15 Civil work under progress

Land acquisitioned delayed, Expected

commissioning by March 2015, Civil

works and erection activity in

progress


3.3 Status of various Associated Transmission Systems (ATS) of upcoming generators

(i) Common System Associated with Costal Energen Private Ltd and Ind-Barath Power

Ltd. (LTOA) Gen. Proj. in Tuticorin area Part – A

Transmission

Elements

Line

Length

(ckm)

Imp.

Agency

Sch

COD

Ant

COD

Constraints/ Remarks

LILO of both ckts of

Tuticorin JV - Madurai

400 kV D/C line at

Tuticorin Pooling Stn.

(Q)

9

PGCIL Jul'14

Jan’15 Line commissioned on

03.01.2015

765 kV Pooling Station

at Tuticorin (initially

charged in 400 kV)

PGCIL Jul'14

Jan’15 Substation

commissioned in Jan’15

(ii) Common System Associated with Costal Energen Private Ltd and Ind-Barath Power

Ltd. (LTOA) Gen. Proj. in Tuticorin area Part - B.

Transmission

Elements

Line

Length

(ckm)

Implem

enting

Agency

Sch

COD

Ant

COD/

Act

COD

Constraints/

Remarks

765 kV D/C Tuticorin

Pooling Station -

Salem Pooling Station

line (Dharmapuri)

(initially charged at

400 kV)

735 PGCIL Dec'14 Dec.’15

3 Gooty-

Madhugiri 400

kV D/C

PGCIL June

2014

May-15

4 Madhugiri

400/220 kV S/S

PGCIL June

2014

Substation is ready. Downstream

network not available

5 Madhugiri-

Yelahanka 400

kV D/C line

PGCIL June

2014

March

2015

Severe RoW problem at Tumkur

(30 Loc), Bangalore Rural (35

Loc) and Bangalore Urban (10

Loc).

400 kV Yelahanka s/s is ready.

LILO point at Yelahanka would be

completed by July 2015

6. Vijayawada-

Nellore 400 kV

D/C

PGCIL Nov.

2014

June 2015 RoW problem being faced at

Krishna Dist. (49 Loc) & Guttur

Dist (23 Loc).

Alternative arrangement is being

planned.


765 kV S/C Salem

Pooling Station

(Dharmapuri) -

Madhugiri Pooling

Station line (initially

charged at 400 kV)

244 PGCIL Dec'14 Jul ’15 Severe ROW

problems in Karnataka

portion of the line.

765/400 kV Salem

Pooling station

(initially charged at

400 kV)

PGCIL Dec'14 June’15 Supply, civil works &

erection under

progress.

Extn. at 765/400 kV

Tuticorin Pooling Stn

PGCIL Dec'14 Mar’15 Supply & civil works

under progress.

Extn. at 400/220 KV

Madhugiri Pooling Stn

PGCIL Dec'14 Mar’15 Award placed in

Oct'11. Engg., supply

& civil works under

progress.

Commissioning

matching with

completion of line

Extn. at 400/220 kV

Salem Sub station

PGCIL Dec'14 Mar’15 Award placed in

Oct'11. Engg., Supply

& civil works under

progress.

It was noted that entire ATS of Coastal Energen may be completed by December 2015.

TN had enquired about any transmission constraints in respect of Coastal Energen

generation. One unit of Coastal Energen is already under COD. SRLDC had informed that

since NTPL units were ready to declare COD by March/April 2015, backing down at

Coastal Energen would be required depending on availability of units at NTPL and

network loading.

(iii)Common Transmission Scheme Associated with ISGS Projects in Nagapattinam/

Cuddalore area of Tamil Nadu - Part-A (a)

Transmission

Elements

Line

Length

(ckm)

Imp.A

gency

Sch

COD

Ant

COD


LILO of Neyveli -

Trichy 400 kV S/C

line at Nagapattinam

Pooling Station

46 PGCIL Oct'14 Complet

ed

Commissioned

400 kV Naga-

pattinam Pooling

Station (GIS)

(provision 765/400

kV in future in the

same Sw.Yd.)

PGCIL Oct'14

Mar’15 Commissioned


(iv) Transmission system associated with IPPs of Nagapattinam/Cuddalore Area–Package A

Transmission

elements

Line

Length

(ckm)

Imp.Agency Ant. COD Constraints/ Remarks

Nagapattinam

Pooling Station-

Salem New

765 kV D/c line

211.73 Powergrid

Nagapattina

m-

Madhugiri

Transmission

Company

Limited

(PNMTCL)

(A subsidiary

of PGCIL)

Mar ‘15 Expected by April 2016

Salem New -

Maiduguri 765

kV S/c line.

234.46 Expected June 2016.

Severe RoW issues being faced

in Karnataka section.

(v) Transmission System Associated with Contingency plan for Evacuation of Power from

IL&FS (2x600MW)

Transmission

Elements

Line

Length

(ckm)

Imp.

Agency

Sch

COD

Ant

COD


LILO of 2nd Ckt of

Neyveli - Trichy 400

kV D/C line at

Nagapattinam

Pooling Stn.

44 PGCIL Jul'15 Jul'15 Award placed in

Aug’14

Strengthening of

Neyveli TS -II to

Neyveli TS-I

expansion link with

higher capacity

conductor

28 PGCIL Jul'15 Jul'15 Award placed in

Aug’14

Extn. of 765/400 kV

Pooling Stn. at

Nagapattinam by 02

nos. bays for

termination of 2nd

Ckt LILO line

PGCIL Jul'15 Jul'15 Award placed. Engg.,

supply, civil works

under progress.

PGCIL had informed HTLS conductor had been received and thus requested for shutdown

(30 - 45 days) of Neyveli TS-I Exp. – Neyveli TS-II line for restringing it with HTLS

conductor. NLC stated that line outage could be considered during the planned unit outages

of NLC TS-I Expansion i.e. during October to December 2015. It was agreed that NLC and

POWERGRID would discuss the matter further bilaterally.


SRLDC had stated that 400 kV Madurai-Udumalpet was getting overloaded and would

further be aggravated with generation at Coastal Energen, NTPL & also wind. Generation

from these stations get pooled at Madurai and thus evacuation of this power beyond was

essential.

(vi) Evacuation of Power from HNPCL (1040 MW) Power Plant

Transmission

Elements

Line

Length

(ckm)/

MVA

cap.

Implemen

ting

Agency

Target

Date

Target

date

completi

on


400 kV Twin

moose D/C Line

from M/s.

HNPCL

Switchyard -

Proposed

Kamavarapukota

S/S (Lot-I, II &

III)

Lot - III

200 ckm

(100 x 2)

APTRANS

CO

Jul ‘15 Oct ‘15 Works awarded. Works

under execution for

Lot-I.

AP informed that out of

730 tower foundation

130 foundation had

been completed.

400 kV Twin

moose D/C Line

from proposed

Kamavarapukota

S/S - Vemagiri

400 kV S/S

APTRANS

CO

Mar ‘16 Tendering process under

progress.

400 kV Twin

moose D/C Line

from Proposed

Kamavarapukota

S/S - Proposed

400 kV Chinna

Korukondi S/S

212 APTRANS

CO

Sept. ‘15 Mar ‘16 40% of works completed.

400 kV Twin

moose D/C Line

from Proposed

Chinna

Korukondi -

Proposed 400 kV

Suryapet S/S

212 APTRANS

CO/

TSTRANS

CO

Works awarded in March

2014. Tower erection

under progress.

Suryapet S/S -

Nandiwanaparthi

S/S 400 kV Quad

D/C Line

240 TSTRANS

CO

Mar’15 Jun’15 Works awarded in Sep-

13 and 115 Towers

erection completed.


400 kV Quad D/C

Line from

Nandiwanaparthi

S/S -

Shankarapally

S/S

222 TSTRANS

CO

Mar’15 Jun’15 Works awarded in Sep-

13 and 58 Towers

erection completed.

Startup Power

Line from M/s.

HNPCL TPP to

400/220 kV

Kalpakka SS

(Supervised by

APTRANSCO)

7 APTRANS

CO

Line Charged on

07.02.2014

Kamavarapukota

Substation

2x315

APTRANS

CO

Mar ‘16 Mar ‘16 Works awarded.

Suryapet

Substation

400/230/132

2x315

TSTRANS

CO

Mar’15 Jun’15 Work awarded on

29.07.2013 and under

progress

2 Nos. of 400 KV

Bay Extensions at

400 KV

Shankarapalli S/S

TSTRANS

CO

Mar’15 Mar’15 Work under progress

2 Nos. of 400 KV

Bay Extensions at

existing 400/220

KV Kalpaka S/S

of HNPCL

APTRANS

CO

All works completed for

1 No. of 400 KV Bay on

07.02.2014

APTRANSCO had informed that 400 kV KV Kota – 220 kV KV Kota and 400 kV KV

Kota – Vemagiri lines had been planned as downstream system and they were under

tendering stage.

It was noted that both the units of HNPCL were expected to commission by June 2015

but entire ATS would be commissioned by March 2016.400/220 kV K V Kota SS would

be critical and was needed to be expedited.

SRLDC had pointed out that maximum evacuation from Vemagiri complex including

HNPCL would be restricted to 600 MW without complete ATS of HNPCL as decided in

the SCC of SR.


(vii) Krishnapatnam Power Transmission Scheme (Unit I : 05.02.2015 (COD); Unit II : June

2015)

Transmission

Elements

Line

Length

(ckm)

Imp.

Agency

Origin

al

Target

Date

Target

date

completio

n

Constraints/

Remarks

Krishnapatnam

TPS- Nellore 400

kV D/C Quad

Line

APTRANS

CO

Commissioned. Line

charged on 23.11.12.

Krishnapatnam

TPS - Bonapally

400 kV D/C Line

179.842 APTRANS

CO

Works completed and

line charged with

LILO arrangement.

Bonapally -

Chittoor Quad 400

kV D/C Line

195.616 APTRANS

CO

Temporary

arrangement .

400kV

Krishnapattanam-

Chittoor

May ‘15 Out of 187 towers 166

towers had been

completed. Works of

around 21 Kms. were

pending.

SRLDC had stated that evacuation from Krishnapattanam JV station would be restricted

to 800 MW until complete ATS was in place.

(viii) Transmission system of KPTCL for evacuation of power from Yeramarus TPS (2x800

MW)

Transmission elements Imp.Age

ncy

Line Length

(ckm)/ MVA

cap.

Sch. COD Constraints/ Remarks

Bellary 400 kV Pooling

Station near ‘BTPS’

KPTCL Work Awarded

Gulbarga 400/220 kV

substation 2x500 MVA.

KPTCL 2x500 Land identified.

Yeramarus TPS -

Gulbarga 400 kV D/C line

with quad moose

conductor

KPTCL Survey completed.

Tendering yet to be taken

up

400 kV switching station

at Chikkanayakanahalli

(C.N Halli) near “Loop in

Loop Out” (LILO) point

on the Nelamangala –

Talaguppa 400 kV lines to

Hassan.

KPTCL Land yet to be identified


LILO of both the circuits

of Nelamangala –

Talaguppa 400 kV lines to

the proposed pooling

station near CN Halli.

KPTCL After CN Halli land

identification, survey

would be taken up.

Termination of 400 kV

D/C line feeding 400/220

KV station at Hassan from

Nelamangala – Talaguppa

line at CN Halli 400 kV

pooling station.

KPTCL After CN Halli land


would be taken up.

Yermarus TPS - Bellary

Pooling Station 400 kV

D/C line with quad moose

conductor

KPTCL 300 Works have been

awarded for 11 km

section only. NIT for the

remaining portion to be

floated by Feb-15

Bellary Pooling Station -

C.N.Hally 400 kV D/C

line with quad moose

conductor

KPTCL 360 After CN Halli land


would be taken up.

Bellary Pooling Station -

New Madhugiri (near

Tumkur) 765/400 kV

station, 400 kV D/C line

with quad moose

conductor

KPTCL 380 Works Awarded and

under progress.

Bellary TPS – Bellary



conductor

KPTCL 10 Survey work in progress.

De-link 400 kV S/C line

running between RTPS-

BTPS-JSW-Guttur with

‘BTPS’ and JSW Bus so

as to retain direct

connectivity between

RTPS and Guttur

KPTCL

Only after all other

Transmission Elements

under Stage I are

commissioned

JSW TPS – Bellary



conductor

KPTCL Only after all other

Transmission Elements

under Stage I are

commissioned.

KPTCL/JSW to discuss

to take up this work as

dedicated transmission

line by the generator.

Constraints in evacuation BTPS Unit-III and Yeramarus TPP had been discussed in 38th

SCPSPSR and it had been decided that joint studies including SRPC,SRLDC,PGCIL


and CEA would be performed and the issue would be further discussed in the next

SCPSPSR.

400 kV Hiriyur-Nelamangala lines would further get overloaded in absence of adequate

downstream network in Madhugiri. Commissioning of 400 kV Bellary PS-CN Halli-

Mysore line would relieve the loading on Hiriyur-Nelamangala line and hence the

commissioning of this section should be taken up on priority

Generation from BTPS, YTPS and JSWEL would get evacuated upto Madhugiri s/s .

However, there is no adequate downstream network to evacuate this generation beyond

Madhugiri.

KPTCL stated that injections at Madhugiri s/s could be evacuated to Yelahanka s/s after

commissioning of 400 kV Madhugiri-Yelahanka lines.

It was pointed out that 400 kV Madhugiri-Yelahanka line was ISTS line and hence

Karnataka should not lean on ISTS network. KPTCL was requested to expedite ATS of

Yeramarus TPP, downstream system at Madhugiri as well as at Yelahanka s/s.

KPTCL had stated that major generators in Karnataka were located on northern side

(above Hiriyur) while loads are concentrated in South Karnataka. Yelahanka

downstream network was planned with UG cable and works were awarded recently. It

would take 18 months to complete the same.

KPTCL had informed the downstream system from Madhugiri s/s as below:

220 kV Madhugiri – Antharasana Halli D/C

400 kV Madhugiri s/s – 220 kV Madhugiri s/s D/C

Tenders for the above line had been placed on 18.03.2015 and it may take 18 months

for completion.

KPTCL informed the downstream network from Yelahanka s/s as below:

400/220 kV Yelahanka s/s - 220 kV Yelahanka s/s D/C

400/220 kV Yelahanka s/s – 220 kV BIAL s/s D/C

(ix) Transmission System required for evacuation of power from Kudgi TPS (3x800 MW in

Phase-I) of NTPC Limited

Transmission

elements

Imp.

Agency

Schedule

d COD

Revised

Target

Date


Kudgi TPS –

Narendra (new)

2xD/C Line

M/s Kudgi

Transmission

Limited

(L&T

Feb-15 June-15

Survey activity is stopped by

villagers of Honnudike and

Hobli Gulur village falling


It was noted that Unit-I of Kudgi TPS was expected to be commissioned by March

2016.

PGCIL informed that SR-II portion of the line 765 kV Narendra (New Kudgi) –

Kolhapur line would be completed by May/June 2015.

KPTCL had informed that their 220 kV lines for startup power would be ready by

September 2015.

It was noted that 400 kV Kudigi TPS- Narendra (New) D/C lines could be expedited,

which would ensure start up power.

3.4 Status of upcoming links having impact on S1-S2

Sl.

No.

Transmission

Element Schedule

Expected

Commissioning

Date

Remarks

1 400 kV Somanahalli-

New Salem

Jun-15 Jul-15 The works under Tamil

Nadu portion had been

completed and severe RoW

problems for 35 Kms. stretch

of Karnataka portion.

45 days shutdown for Hosur-

Salem line would be required

for stringing of this line.

PGCIL would coordinate with

Tamil Nadu.

Infrastructur

e

Development

Projects

Ltd.)

under Tumkur (Taluk &

District) (Effected span:

Approx. 2 KMs.). Matter is

brought to the notice of District

Administration.

Narendra(new)-

Madhugiri 765 kV

D/C Line

Dec - 15 June- 16 The villagers are not allowing

for any construction work at

the respective locations and

asking for huge compensation.

Matter is brought to the notice

of District Administration.

These locations are nearer to

400/220 kV POWERGRID

Bidadi substation. Being

terminating point, no

alternatives available for re-

routing the line.

Madhugiri -Bidadi

400 kV D/C

(quad) Line

Dec - 15 June- 16


2 400 kV Mettur-

Thiruvalam Jan. 2015 April 2015

Permission from Hubli Railway

division had been received

3 400 kV Mysore-

Kozhikode

May. 2015 June 2015 Held up due to ROW issue.

Work started in October 2014

with Admn. Support as

directed by court.

PGCIL informed works under

progress. Stringing works also

started.

4

400 kV Mangalore

(UPCL) -Kasargode-

Kozhikode D/C Line

In 26th

SRPC meeting,

following were noted:

Approved by Standing

Committee & SRPC.

KPTCL stated that they had

furnished load flow studies

and their comments keeping

in view of 2000 MW HVDC

link at Madakathara and

hence the necessity of the

line to be reexamined.

KSEB, CTU & SRLDC

stated that the line was

absolutely essential.

In the 38th

Meeting of

SCPSPSR (07.03.2015) it was

decided that implementation of

this line could be initiated after

considering use of Karnataka

ESCOMS, if communicated

within a month.

In the 106th

meeting of OCC held on 10th

April 2015 it was noted that ICTs at Kozhikode

S/S of PGCIL have not been commissioned. SRPC vide letter dated 15.04.2015

(Annexure-I) had requested PGCIL ensure that the Mysore - Kozhikode lines and the

ICTs at Kozhikode come up simultaneously to avoid any evacuation constrains.

3.5 Critical Intra-regional transmission elements

Sl.

No. Transmission Element Expected CoD Remarks

1 765 kV Salem- Madhugiri June 2015 Severe RoW problem near Madhugiri.

2 400 kV Edamon-Kochi Govt. of Kerala issued G.O dated

19.08.2014, recommending additional

compensation

KSEB informed that Kerala Govt. had

agreed for the compensation of 5 times

market value. Still talks were going on.


3.6 Status of following upcoming inter-regional transmission schemes under various

stages are furnished at – Annexure - II.

a) 765 kV Narendra – Kolhapur D/C line,

b) 765 kV Wardha – Nizamabad D/C line,

c) WR-SR 6000 MW HVDC Bipole Link [Raigarh (Chhatisgarh) -Pugalur/Trichur

(TN/KER)],

d) Angul - Srikakulam PS 765 kV D/C line,

e) Additional inter-Regional AC link for import into Southern Region, i.e., Warora-

Warangal - Hyderabad- Kurnool 765 kV link

f) System strengthening within SR for transmitting power beyond Vemagiri

3.7 Transmission line/elements constraints being observed in real time by SRLDC are

given below. The over loadings of various transmission lines and ICTs in pictorial

form are at Annexure-III

Constraint Remarks

Overloading of 400 kV

Kolar-Hosur D/C line

S2 Bid area drawal limited by N-1 of these lines.

Even after commissioning of Mettur-Tiruvalam & Mysore-

Kozhikode lines the limiting constraints could be there on

these lines.

Overloading of 400kV

Hiriyur-Nelamangala DC

line:

With Full generation at Jindal and BTPS, and wind generation

high, the flow on 400kV Hiriyur-Nelamangala DC line

continuously near to 550MW and may worsen if generation at

UPCL is low.

400kV Gooty-Madhugiri-Yelahanka DC line would relieve

constraint to some extent

Yeramarus Evacuation system, especially CN Halli corridor

may relieve the constraint

220 kV DC Hiriyur-Gbnur commissioned recently- Relief of

about 30-40 MW on each line obtained


Udumalpet-Palakkad DC

line:

Kerala drawl is mainly through 400kV Udumalpet-Palakkad

DC line.

Kerala drawl capability would be limited by this line.

Drawal capability would increase with 400 kV D/C Mysore-

Kozhikode line

Overloading of these lines would be relieved only with the

commissioning of Mysore-Kozhikode line.


Jindal-BTPS SC Line: With the full generation at Jindal, this line is getting loaded

beyond 650 MW.

Other evacuation paths are 400kV Jindal-Guttur and Two

ICTs.

But at 220 kV side also generation is available.

Yeramarus system may relieve the constraint


Overloading of Gazuwaka

ICTs (2 x 315 MVA) It was noted that there was some space constraint for

augmentation at Gazuwaka s/s.

Overloading of Nellore ICTs

(2 x 315 MVA) It was observed that loads at Nellore had increased drastically

in recent times.

AP informed that 220 kV Nellore-Sullurpet D/C line had been

charged at one end and other end bay works were pending.

In the 38th

Meeting of SCPSPSR (07.03.2015) reorientation of

Nellore – Vijayawada 400kV D/c line was agreed.

Overloading of Vemagiri

ICTs (2 x 315 MVA) It was observed that N-1 violation had been observed up to

60% of the time in the month of October 2014.

AP was requested to coordinate with CTU in order to curtail

overloading.

Overloading of Somanahalli

ICTs (2 x 500 MVA) Frequent N-1 violation were being observed.

Redistribution/ reconfiguration of 220 kV transmission

lines around these substations is required.

In the 26th

meeting of SRPC the following had been noted:

KPTCL had informed that comprehensive plan for

Bengaluru (7,500 MW) has been envisaged and had been

approved by the Board. Presently the load met was about

2,700 MW out of 5,600 MVA capacity. About Rs.1,100

Crore had been earmarked for the strengthening works.

Tender had been finalized for strengthening

Somanahalli - Peenya section and they were planning

to complete it within one year.

Overloading of Mysore ICTs

(2 x 315 MVA) It was observed that N-1 violation had been observed up to

35% of the time in the month of December 2014.

PGCIL informed that augmentation works had been awarded.

It was emphasized the need for strengthening of downstream

network.

Overloading of

Kalvinthapattu ICTs (2 x 315

MVA) & Pugalur ICTs (2 x

315 MVA)

States were requested to plan for strengthening of downstream

network.

In the 26th

meeting of SRPC, PGCIL had informed that ICTs at Kalvinthapattu,

Mysore, Pugalur, Trichy & Somanahalli were expected by 2017 (award placed during

September 2014).


3.8 SRLDC had also presented the following transmission system constraints in the state

network wherein states were requested to update the system planned by the state

Constraint Remarks

220 kV Bangalore Metro

Network 220 kV Metro Networks (Bangalore Urban area) are now

radialized to prevent overloading of lines.

The radialization decreases the reliability of supply.

KPTCL to update Planned 220kV Network - to meet the

future demands of Bangalore city and effective utilization of

additional Transformer capacity approved

Overloading of 220 kV

Shoolagiri-Hosur (TN) –

Yerandahalli-Somanahalli

SC line

Somanahalli, Yerrandahalli and Hosur are Industrial areas.

220 kV Yerrandahalli is connected with Hosur (TN) and

Somanahalli. Normally, 220 kV Yerrandahalli split and part

of load is fed from Hosur (TN) as the entire load cannot be

met from either side (Somanahalli or Hosur). The line loading

on this line also causes high flows on Shoolagiri-Hosur 230

kV S/C line.

KPTCL had informed that they were planning alternate

arrangements for Yerrandahally which was likely to be in

place by July 2015. 400 kV Mylasandra SS had been planned

as part of alternate arrangement. Contract had also been

awarded however there were some disputes in land

acquisition. Another 66 kV line had also been planned. With

commissioning of Mylasandra S/S, loading on Somanahalli -

Hosur would get reduced. 66 kV cable laying works between

Velankeni- Naganathapuram were under progress and about to

complete. Works on 66 kV Nagnathpuram - Electronic city

(OH line) D/C, Sarjapura-Atibele, Sarjapur - Chandapura &

Sarjapur - Bommasandra were also under progress.

SRLDC stated that even if alternate arrangement was made by

KPTCL, only limited relief would be obtained at Shoolagiri.

The intra state system at Hosur/ Shoolagiri was needed to be

strengthened by TANTRANSCO.

TANTRANSCO informed that approval had been accorded

for 2nd circuit of Hosur-Shoolagiri and Uddanapalli (near

Hosur) SS .Contract and civil works had been awarded for

Gurubarapalli S/S near Shoolagiri.

220 kV Sharavathy-Shimoga

lines (4 Nos.) and 220 kV

Sharavathy – Talaguppa D/C

With full generation of Sharavathy (>900 MW) there is no N-

1 reliability on 220 kV Sharavathy-Shimoga lines (4 Nos.

>150 MW each) and 220 kV Sharavathy-Talaguppa D/C

(>180 MW each). With the commissioning of rearrangement

at Sharavathy-Talaguppa, the constraint on 220 kV

Sharavathy-Talaguppa D/C would be solved to a certain

extent.


SRLDC enquired the status of rearrangement of 220 kV

Sharavathy-Shimoga line which was proposed earlier.

KPTCL informed that one circuit of Sharavathy-Shimoga

would be converted to Sharavathy-Talaguppa. With this

rearrangement there would be 3 lines to Shimoga and 3 lines

to Talaguppa from Sharavathy.

Constraints in Coastal and

South AP Southern and coastal AP loads have increased and with

increased generation at Rayalaseema TPP (5 units on bar at

present, 220 MW each and 5th

Unit has been added without

augmenting the evacuation which was designed for 2 units of

220 MW) the loadings on the following 220 kV lines are of

concern, 220 kV Chinakampalli-Renigunta, 220 kV

Chinakampalli-Rajampet, 220 kV Chinakampalli-Kalkiri SC

line, 220 kV RYTPP – Chinakampalli D/C line, 220 kV

Tadikonda-Ongole, 220 kV VTS-Podili SC line, 220 kV VTS-

Narsaraopet SC

SRLDC pointed out that 220 kV Rayalseema TPS-

Chinakampalli line were severely getting overloaded.

AP informed that 400 kV Rayalseema TPS - Muddanur was

expected by May/June 2015. 400 kV Kalkiri S/S was still

under estimation stage.

It was noted that as Rayalseema TPS Stage-IV was expected

during 2015-16 the constraint would further be aggravated

without the proper evacuation scheme of Rayalseema TPS.

Constraints in Chennai 230

kV System Presently Chennai area 230 kV network is heavily loaded. 230

kV Almatty-Manali DC line, 230 kV Manali-Koratur, 230 kV

Kalavinthapattu S.P.Koil, 230 kV Kalavindapattu-Sruseri, 230

kV NCTPS-ETPS line are severely loaded.

TN was requested to update the planned 230 kV network for

evacuation of Chennai generators.

Constraints in 230 kV

Evacuation lines of MTPS

and Kundah complex

230 kV Kundah PH4-Thudialur line, 230 kV MTPS-III Gobi

line, 230 kV MTPS-Ingur line and 230 kV Pugalur 4 –

Mywadi line.

N-1 violation is frequently observed for MTPS-Gobi line.

TN was requested to update the strengthening schemes

planned for MTPS and Kundah complex.

TN informed MTPS-Arasur and MTPS-Tingalur had

commissioned.

Northern Kerala System At present the North Kerala loads are largely fed from

400/220 kV Madakathara, 400/220 kV Palakkad and through

220 kV Kadakola-Kaniyampeta link which is feeding loads of

Kaniyampeta, Vadakara and Thali paramba through split bus

at Areakode and Kanhirode. The transmission line feeding to

these stations are already highly stressed.


Voltages had been very low during peak load conditions.

KSEB informed they had installed 1000 MVAR capacitor to

contain low voltages.

SRLDC pointed out more reactive power management is

required in the North Kerala area to contain low voltages.

Palakkad and Trichur areas were facing severe low voltages

during peak load conditions.

Kerala was requested to expedite the plan to relieve the

constraints.

Stage-1 Wind evacuation

system of TNEB : 400 kV

Kanarapatti s/s, 400 kV

Kayathar s/s, 400 kV

Tirunelveli-Kanarpatti-

Kayathar DC line, 400 kV

Kayathar-Karaikudi-Pugalur

DC line

In the 26th

Meeting of SRPC the following had been noted:

TANTRANSCO had informed that Kanarpatty S/S

would be commissioned by next year, while Kayathar

S/S had been commissioned. The situation had eased

to some extent with the commissioning of Kayathar

S/S. Besides substantial wind presence, 2,000 MW of

solar project were also coming up in the state. Hence,

as a comprehensive measure, network strengthening at

400 kV and 230 kV was planned. Under kfW scheme,

various 400 kV and 230 kV network strengthening

schemes were under execution. 15 number of capacitor

bank had also been planned to be installed shortly to

address under voltage issue.

SRLDC had pointed out that since wind generation

had come down the situation had presently eased.

With wind generation picking up from May 2015

onwards, there could be evacuation constraints

coupled with low voltages. It was also suggested that

TN may kindly furnish full details of the schemes

along with schedule of commissioning dates.

TANTRANSCO agreed to furnish the same.

Congestion on 400/230 kV Tirunelveli ICTs. 230 kV

Kayathar-Tirunelveli, 230 kV Udayathur-Tirunelveli, 230 kV

Veerannam-Tirunelveli etc.

Stage-1 Wind evacuation was planned when Wind installed

capacity was 4,000 MW

Present wind installed capacity is about 7,300 MW

230 kV Line flows are very high and voltages are very low

during high wind condition.

TN was requested to update the status of the Transmission

system planned.

Strengthening of

Hyderabad downstream

system

In the 26th

meeting of SRPC, TSTRANSCO had agreed to

furnish the details.


3.9 The low voltage nodes in the Southern Region are given below. States were requested

to restrict MVAR drawal & also install UV relays in those areas:

S.No. Nodes Season/antecedent conditions

1 400 KV Somanahalli s/s During peak load conditions

2 400 kV Nelamangala s/s During peak load conditions

3. 400 kV Udumalpet s/s During peak load conditions and high wind

period

4 400 kV Salem s/s During peak load conditions and high wind

period

5 400 kV Palakkad s/s During peak load conditions

6 400 kV Trichur s/s During peak load conditions

SRLDC pointed out that more reactive management is required in the North Kerala

areas. In Kerala and Tamil Nadu overloading of 230 kV lines is one of the causes for

under voltage problems. Without adequate reactive power management the ATC may

have to be restricted.

SRLDC had enquired whether RGCCP Kayamkulam could run as synchronous

condensers which would help improve voltages. KSEB had been requested to interact

with NTPC on this matter.

In the OCC meetings it was noted that the OLTC for Madakatara ICTs was not

functional. SRLDC had expressed concern and had requested KSEB to expedite the

works.

3.10 SRLDC had presented the following high voltage nodes in the Southern Region and

requested to expedite the commissioning of reactors :

S.No. Nodes Season/antecedent conditions

1 400 KV Vijayawada s/s Whole year

2 400 kV Vemagiri s/s Whole year

3. 400 kV Gooty s/s

Monsoon period and off-peak period 4 400 kV Kurnool s/s

5 400 kV Srisailam s/s

6 400 kV Kaiga s/s Whole year

7 400 kV Guttur s/s Whole year

8 400 kV Narendra s/s Whole year

9 400 kV Tirunelveli s/s

During off-peak

10 400 kV Kudankulam s/s

11 400 kV Sriperumbudur s/s

12 400 kV Raichur s/s

13 400 kV Kurnool s/s

14 400 kV Nellore s/s


KPTCL had informed that line reactor at Guttur and bus reactors at Hoody, Nelamangala

& Talaguppa would be commissioned by June 2015.

KPCL had informed that Raichur bus reactors would be commissioned by June 2015.

NPCIL had informed they were moving ahead with the 2 x 125 MVAR reactors at Kaiga

as agreed in the Standing Committee.

APTRANSCO had informed that 80 MVAR reactor at Vemagiri was commissioned on

5th

March 2015.

Bus reactor Guttur was commissioned on 23rd

March 2015 by KPTCL

All utilities were requested to kindly expedite commissioning of reactors before onset of

the monsoon.

3.11 SRLDC presentation on the planned transmission system ISTS and important corridors in

2016-17 which is at Annexure-IV.

3.12 SRLDC presentation on the envisaged transformation capacity by 2016-17 in various

states is available at Annexure-V. All states are requested to plan the downstream

network matching to planned transformation capacity and furnish the details to

SRPC/SRLDC.

3.13 All the states had been requested to furnish the feedback/details on the above all

issues within a period of one month. The details include transmission system planned,

LGBR, ISTS requirement, detailed status of upcoming generation projects (state & IPPs),

details regarding spatial load growth etc.

Summary

All the utilities were requested to kindly appraise their Management of the

constraints being faced and also likely to be faced.

Concrete action plan needed to be finalized and implemented.

Some of the constraints were of emergent nature and thus fast track action

was needed to be taken.

All the concerned utilities would furnish the updated information for enabling

status update to SRPC/TCC.

Wherever downstream network is overloaded, measures to relieve the

congestion needs to be taken.

Wherever augmentation of capacity was planned, downstream network also

needed to be planned.

Planning aspects needed to be taken up with CEA/CTU.

Load Generation Balance Assessment

Internal Generation

Intra-State IPPs


ISTS Requirement

Import Requirements

LGB to assessed for

Each Year – next five year

Subsequently for each fifth year

Peak & Off peak conditions

For different seasons

For coordinated development process aiming at perspective optimization in

meeting the growth targets, it would be appropriate that the State

Transmission Utilities prepare their State Electricity Plans taking advantage

of development plans for regional grid system and focusing on the specific

requirements of the concerned State.

To ensure that the planned transmission network gets implemented as per the

schedule, the issues related to ROW, forest clearance and various other

clearances would need to be addressed with the appropriate authority.

States should come up with evacuation for its internal generators and not lean

on ISTS.

3.14 400 kV Trichur-Kozhikode line (Madakkathara- Areakode)

The following had been noted till 26th

Meeting of SRPC:

KSEB had stated that this line had already been approved as Regional

System Strengthening Scheme. North Kerala would benefit since 400 kV

supply could be availed either from Udumalpet or from Mysore for all the

400 kV substations in Kerala. Multi circuit & multi-level circuit was their

requirement for surrender of corridor.

PGCIL had sought utilization of existing 220 kV Madakkathara-

Malaparamba-Areakode S/C feeder. There was no possibility of

surrender of RoW of KSEB line presently since energy security of

Malabar region was involved. Line works could be taken up only after

commissioning of the 400 kV Mysore-Kozhikode line. PGCIL had been

requested to initiate the process so that construction could commence

immediately after 400 kV Mysore-Kozhikode line was commissioned.

3.15 Closing of Upper Sileru-Balimela Line

3.15.1 In the 26th

meeting of SRPC the following had been noted:

It had earlier been agreed that the Upper Sileru- Balimela Line be closed

again on an experimental basis. Apprehensions of AP would be addressed

including those relating to quick exchange of codes.

Line was needed to be closed at the earliest and that the matter was also

being reviewed by higher bodies.

3.15.2 Subsequently it was noted in the 105th

OCC Meeting (10.03.2015) that from 8th

January 2015 the line had been restored and idle charged from Upper Sileru end..

A Meeting had also been conducted in MoP on this issue.


3.16 Utilization of Jeypore - Gazuwaka link to its full capacity i.e 1000 MW

3.16.1 The issue regarding Utilization of Jeypore – Gazuwaka link to its full capacity of 1,000

MW was earlier raised. Subsequently in the OCC meeting it had been noted that on

account of issues of low voltage at Jeypore end and also upstream line loadings, at

present ATC allowed on Jeypore (ER)-Gazuwaka (SR) HVDC link (rated capacity

1000 MW) was of the order of around 700 MW.

3.16.2 SRPC vide letter dated 12.02.2015 (Annexure-VI) had requested CTU, PGCIL that

this issue be examined and SRPC be informed accordingly. Reply dated 11th

March

2015 of CTU in this regard is furnished at (Annexure - VII)

4. TRANSMISSION LINES APPROVED IN 38th

MEETING OF SCPSPSR

4.1 The 38th

Meeting of Standing Committee on Power System Planning of Southern

Region (SCPSPSR) was held on 7th

March 2015. The Minutes of the Meeting is

enclosed as (Annexure-VIII)

4.2 Modifications in the scope of Raigarh – Pugalur – Kerala 6000 MW HVDC

Transmission System:

In the meeting PGCIL had proposed modifications in the scope of HVDC terminals

at Pugalur and NorthTrichur in addition to the set of 6000 MW terminals at Raigarh

and Pugalur. Also the Pugalur – N Trichur terminals had been proposed to be built

with VSC based technology instead of the earlier conventional HVDC technology. In

this regard, a Joint Meeting of Standing Committee of SR and SR was conducted on

20th

April 2015 at New Delhi.

5. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE& UMPP

5.1 NTPC- Kudigi TPS Stage-I (3x800 MW)

In the 26th

Meeting of SRPC, the following had been noted:

NTPC had informed that Unit-I synchronization was planned for

February 2016 while CoD was expected by April 2016. CoD of Unit –II

was expected subsequently after 6 months.

CTU had informed that AP DISCOMs (undivided) were having share of

418 MW. After reorganization, revised application for LTA was needed

to be furnished by NTPC/AP /Telangana.

TSTRANSCO had informed that sharing percentage as per the AP

Reorganization Act 2014 holds good for any project under construction

also. They would ensure the needful in coordination with NTPC.

Director (Grid & Tr), APTRANSCO had stated that any sharing would

need to be carried out as per the Reorganization Act 2014.


5.2 NLC-Neyveli TS-II Expansion (2x 250 MW)

5.2.1 In the 26th

Meeting of SRPC held on 20th

December 2014 , NLC had informed that

bulk of the issues relating to Heat Exchanger and Refractory works had been

resolved. CoD of Unit–I was expected by first week of January 2015. Unit II was also

in advanced stage of commissioning and CoD of the unit was also expected by end

January 2015.

5.2.2 In the 27th

Meeting of Commercial Sub Committee of SRPC held on 17th

March 2015

NLC had informed that CoD of both the Units would be by March 2015.

5.2.3 Subsequently, CERC wide order dated 01.04.2015 had allowed extension of time for

injection of infirm power into the grid for the commissioning tests including full load

test of Unit-I for a further period up to 30.6.2015 or actual date of commercial

operation, whichever is earlier.

5.2.4 CoD of Unit- II of TPS– II Expansion was declared with effect from 22nd

April 2015.

5.3 NLC - New Thermal Power Project (2x 500 MW) at Neyveli

The following had been noted in the 26th

Meeting of SRPC:

CoD of Unit-I & Unit –II was expected by October 2017 & April 2018

respectively.

5.4 NPCIL-Kudankulam Nuclear Power Project (KKNPP) Stage-I (2x1000 MW)

5.4.1 The following had been noted in the 26th

Meeting of SRPC:

Unit- I was running at 1,000 MW and CoD was expected before 22nd

January 2015. Unit –II was planned to be critical by end April 2015 while

synchronisation was planned by July 2015.

5.4.2 Subsequently Unit-I had been put on Commercial Operation w.e.f 0000 Hrs of

31.12.2014.

5.4.3 A Special Meeting with KKNPP/NPCIL, SRLDC & SRPC Secretariat was held in the

Conference Hall of SRPC on 07th

April 2015 to discuss the operational and

accounting issues in respect of KKNPP Units. The Record Notes of the Meeting is

available at www.srpc.kar.nic.in/website/2015/meetings/special/KKNPP-MTG-07-

04-15.pdf.In that Meeting, the following was decided in respect of scheduling and

accounting of energy exchanges by both the Units of KKNPP:

Till commercial operation of Unit-II, the energy drawn for common station

auxiliary – CSAT would be accounted to Unit-I. With both Units under

commercial operation ,CSAT drawal would be shared in 50:50 ratio by Unit I

& II.

http://www.srpc.kar.nic.in/website/2015/meetings/special/KKNPP-MTG-07-04-15.pdf

http://www.srpc.kar.nic.in/website/2015/meetings/special/KKNPP-MTG-07-04-15.pdf


Unit-I and Unit-II energy exchanges would be computed based on SEMs at

outgoing feeders, GT-1, GT-2, RAT-1, RAT-2 and CSAT.

Infirm power injection by Unit-II would be accounted in line with the

methodology followed during infirm power injection by Unit-I. As in the case

of Unit-I, exemption for scheduling infirm power for Unit-II also needs to be

obtained appropriately. Scheduling of infirm power injection by Unit-II would

commence after stabilized operation of the unit (after achieving 200-300 MW

stabilized generation). The infirm power injected prior to scheduling would be

accounted post-facto based on the share allocation ratio of beneficiaries of

Unit-II.

After commercial operation of both units, the scheduling and accounting

would be carried out separately (unit wise).

When both the units under commercial operation, the energy accounting

would be based on the outgoing feeders. The energy exchanges based on the

SEMs on the outgoing feeders would be apportioned based on the SEM

readings of GT-1, RAT-1 & 50% of CSAT for Unit-I and GT-2, RAT-2 &

50% of CSAT for Unit-II.

5.5 BHAVINI- Kalpakkam PFBR (500 MW)

In the 26th

Meeting of Commercial Sub-Committee of SRPC held on 21st November

2014, BHAVINI had informed that the unit would be commissioned during March

2015.

5.6 NLC Tamil Nadu Power Limited (NTPL - JV Company of NLC & TANGEDCO)

at Tuticorin (2x500 MW)


Meeting of SRPC:

NLC had informed that they had received ‘Consent to Operate’ pending forest

clearance. Synchronization of Unit-I was planned during January 2015 while

CoD was scheduled by February 2015. CoD of Unit –II was scheduled by

March 2015.

5.6.2 A Meeting with NTPL, TANTRANSCO, SRTS-II, SRLDC & SRPC Secretariat

was held on 20th

April 2015 to discuss the metering arrangements and

accounting issues in respect of NTPL Units. The following had been noted in

this Meeting:

NTPL informed that Unit-I would be declared on commercial

operation within ten days and Unit-II by end of May 2015.

Till commercial operation of Unit-I, infirm power injection of both

the units would be carried out as a whole of the station. Computation

would be based on SEMs on outgoing feeders on 400kV &230kV

side.


After Commercial operation of Unit-I, Unit-I &Unit-II energy

exchanges would be computed by apportioning the sum of the SEMs

at outgoing 400kV feeders, 230 kV feeders (after charging of LILO)

in proportion to the SEMs at HV side of GT-1& GT-2. Stand by

SEMs at LV side of GTs would be provided within 15 days.

Providing of Standby SEMs at LV side of GTs should not be insisted

by SRLDC for commercial operation of Unit-I. SRLDC expressed

that in the event of fuse failure on HV side of GT, energy

apportioning could not be carried out.

The SEMs at NTPL on the 230kV feeders would be treated as drawal

points of Tamil Nadu.

The methodology for accounting of drawal of energy during

shutdown condition of the station through 400 kV feeders as well as

230 kV feeders would be in line with the approved methodology

being adopted in respect of other ISGS (CGS) operating in SR.

TANTRANSCO stated the decision in this regard needed to be taken

by their management. They would appraise the methodology being

followed in SR to their management.

5.7 Krishnapattanam UMPP (6x660 MW)

In the 26th

Meeting of SRPC, APTRANSCO had informed that a Meeting with Developer

and Procurers was conducted on 21st August 2014. A Consultant had been appointed to

look into commercial, financial and legal issues. Report of the Consultant was expected

within one month time which would be shared with other Procurers.

5.8 Cheyyur UMPP (4000 MW)


Meeting of SRPC:

TANTRANSCO had informed that Request for Qualification (RfQ) document

was opened on 20.11.2013. Request for Proposal (RfP) documents were

scheduled to be opened on 22.12.2014. The 1st Unit would expected to be

commissioned in 42 months from zero date (2018-19) and the subsequent units

would be commissioned at the interval of six months.

5.8.2 As per the Minutes of 38th

Meeting of SCPSPSR, M/s Costal Tamil Nadu Power Ltd.

(CTNPL) a SPV of PFC had applied for connectivity and LTA to CTU. The

beneficiaries of the project are Southern Region-3,100 MW ( Tamil Nadu -1,600 MW,

Karnataka – 800 MW, Andhra Pradesh – 400 MW & Kerala – 400 MW), Western

Region – 400 MW (Maharashtra) and Northern Region – 500 MW ( Uttar Pradesh –

300 MW & Punjab – 200 MW).


5.9 Schedule of synchronizing/commissioning of the new projects of NTPC, NLC, NPCIL,

BHAVINI, and Joint Venture & UMPP is furnished below:

Station Unit Installed

Capacity

MW

Scheduled date of

synchronizing /

commissioning

Remarks

NTPC

Kayamkulam I, II,

III

1050/

1950

12th

Plan Gas supply by 2014. Kerala

requested for 500 MW. TN &

Puducherry would consider after

knowing the tentative tariff. AP &

KAR DISCOMs were not willing to procure the power.

Kudgi TPS

Stage-I

I,I,

III

3x800=

2400

Unit-I :

Synchronization

by March 2016

Unit-II : :Synchronization

by October 2016

NTPC informed that they had

requested KPTCL for startup

power in August 2014.

KPTCL informed that the

works were under progress and

there had been RoW issues.

Expected date of completion

was August 2015.

NLC

Neyveli-II Expn. I 250 CoD by June 2015 Injection of infirm power

allowed up to 30.06.2015

II 250 CoD by May 2015 Startup power estimate furnished

to SRLDC.

New Thermal

Power Project

I 500 October 2017

II 500 April 2018

Sirkali TPP I, II,

III

3x660 From GoI approval

Unit I – 52 months

Unit II – 58 months

Unit-III – 64

months

PPA has been signed. Fuel

imported coal. Approval of

Feasibility Report was awaited

from NLC Board.

NPCIL

Kudankulam

Stage-I

I 1000 CoD 31.12.2014

II 1000 Synchronization by

Aug./ Sep. 2015

NPCIL informed that fuel

loading would be done in June

2015

BHAVINI

Kalpakkam

(PFBR)

I 500 September 2015


NTPL (JV Company of NLC & TANGEDCO)

Tuticorin I 500 Original schedule:

40 months after

LOA. LOA signed

on 28.01.2009

Anticipated

schedule: by April

2015

Achieved full load on 10th

March

2015 at 1748 hrs.

II 500 Original schedule:

45 months after

LOA. LOA signed

on 28.01.2009

Anticipated

schedule: by May

2015

Synchronized for the first time at

09:27 hrs on 09.04.2015.

UMPP

Krishnapattanam 3960

(6x660)

The developer had stopped the

works at site and the project may

get delayed. Meeting of

Developer & Procurers was held

on 21.08.2014. Consultant

report was awaited.

Cheyyur 4000 The project is

expected to be

commissioned

progressively from

March 2019 - 2021

Site finalized during meeting of

CMs held on 04.08.08. RfQ had

been issued and project

developer (M/s Coastal Tamil

Nadu Power Ltd. which is SPV

of PFC) had applied for LTA to

CTU. RfP would be opened on

22.12.2014.

6. NEW PROJECTS OF STATE SECTOR & IPP

6.1 Updated status of new projects of State sector & IPPs is furnished below :

Sl

No.

Name of project Located

in

Owner Capacity

in MW

Commissioning Schedule /Remarks

1 Krishnapattnam JV AP State 1600 U-I: COD declared on 05.02.2015

U-II: COD by June 2015

2 Rayalaseema TPS

ST-IV

AP State 600 2015-16

3 Meenakshi PH-II AP IPP 700 2016-17

4 Simhapuri PH-II AP IPP 150 Synchronized on 30.12.2014

5 East Coast Energy

Thermal

AP IPP 1320 2015-16

AP : 300 MW

6 Thermal Powertech. AP IPP 1320 Unit-I: CoD on 2nd

March 2015

Unit-II : 2015-16

Unit-III : 2016-17

Undivided AP: 500 MW. PPA signed.

TS : 100 MW


7 NCC Krishnapattnam AP IPP 1320 Unit I & II : COD by 2015-16

AP : 250 MW

8 Hinduja NPCL,

Vizag

AP IPP 1050 CoD by June 2015

9 Bellary TPS U-3 KAR State 700 CoD by Sept / Oct 2015

10 Yeramarus TPS KAR State 1600 Unit-I : by October 2015 and CoD by

December 2015

Unit II: Synchronization by December

2015 and CoD by February 2016.

11 Coastal Energen TN IPP 1200 Unit-I : CoD declared on 23.12.2014

Unit-II: CoD by April 2015.

12 IL&FS TN

IPP 1200 90% of the works completed.

Environmental clearance is awaited.

13 Kakatiya TPP ST-II TN

State 600 August 2015.

14 Singareni TN

IPP 1200 Unit I : COD by October 2015

Unit II : COD by December 2015

7. PAYMENT OF WHEELING CHARGES

7.1 As per the procedure for calculation of Node wise PoC charges a Load Flow base case

up to 110 kV network is modeled which gets truncated to 400 kV equivalence

network. Due to this network truncation, power flow from upstream state to down-

stream state through voltage class below 400 kV gets replaced with a load equivalent

to power flow through such lines at upstream state. This results into by upstream state

bearing the cost of ISTS equivalent to power flow to downstream state.

7.2 To address this issue, in the 21st Meeting of SRPC, it had been decided to raise the

rate of Wheeling Charges of Inter-State Lines from 2.5 to 7.5 paisa/Unit of energy

wheeled ( 2.5 paise + 5 paise compensation).

7.3 Since then the Central Electricity Regulatory Commission (Sharing of Inter State

Transmission Charges and Losses) (Third Amendment) Regulations, 2015 has been

notified to be implemented from 01st May 2015. In the same, it has been decided not

to truncate the base case load flow model. In view of this the wheeling charges need

to be again revised to 2.5 ps/unit.

8. RESERVE SHUT DOWN (RSD)

8.1 In the 104th

Meeting of Operation Coordination Sub-Committee of SRPC held on 10th

February 2015, the following had been noted:

There was a scheme for RSD being followed in Western Region. SRPC

Secretariat had presented the RSD procedure being followed in WR.

In WR, Reserve Shut down of costlier unit was being considered for a minimum

period of 3 days (72 hrs).

Constituents had expressed that in the present scenario, RSD may not be suitable

in SR. This region was in surplus only for few hours in a day and not even more

than a day on sustained basis. Constituents also had expressed ISGS capacity


was just 20 % of the total capacity while balance 80% was internal generation in

states.

KSEB had stated that constituents could consider surrender of costly ISGS

power while cheaper power could be purchased from other regions, subject to

availability of ATC.

8.2 In the 27th

Meeting of Commercial Sub-Committee of SRPC held on 17th

March 2015,

the following had been noted:

The issue regarding sustained underdrawal by some of the utilities had been

deliberated in the Meetings of OCC. In the present operating regime,

overdrawal / underdrawal is allowed only within certain limits. RSD was one

possible scheme which could be adopted to minimize heavy underdrawal.

However, any other scheme also could be considered. During the ensuing Wind

Season followed by SW monsoon, economical operation of the grid would be

possible if some identified scheme is in place.

NLC had opined that annual maintenance of units could be planned during

surplus conditions. It was clarified that the regional outage planning was being

carried out considering anticipated deficit/surplus position in the Region. The

scheme proposed was during surplus conditions which could arise even after

availing planned shutdown of units. However, duration of such surplus needed

to be more than the minimum time required for economical shutdown/ start up

operation of units

After deliberations, utilities had agreed to consider the scheme and revert back.

8.3 The presentation made by SRPC Secretariat on RSD in the OCC & Commercial Sub-

Committee Meetings is furnished at (Annexure-IX) .

9. EMERGENCY RESTORATION SYSTEM (ERS)

9.1 In the 26th


APTRANSCO had informed that tenders for 2 sets of ERS of 10 towers each

had been floated.

TSTRANSCO had informed that procurement of 1 set of ERS was under

process.

KPTCL had informed that they were having 2 set of ERS (10 towers each).

KSEB was requested to procure at least 1 set of ERS to comply with the

Regulations.

TANTRANSCO had informed that procurement of 2 sets of ERS was under

process.

The Committee had approved procurement of one set of 400/220/33 kV ERS

Substation for Southern Region by POWERGRID. PGCIL would endeavor to

get the same funded through PSDF.

9.2 Subsequently, SRPC vide letter dated 12.03.2015 (Annexure-X) had forwarded a copy

of letter dated 05th

December 2014 from Secretary (Power) addressed to Chief


Secretaries of States/UT regarding procurement action of ERS infrastructure. The

availability and proposed plan for development of ERS in Southern Region is as

follows:

Sl.

No.

State Utility / PGCIL Availability

of ERS sets

Additional +

ERS set to

be procured

Remarks

1 PGCIL- SR-I 1 2

PGCIL- SR-II 1

2 ANDHRA PRADESH - 3 To be located at

Vishakhapatnam,

Vijayawada, Nellore

3 KARNATAKA - 2

4 KERALA - 1

5 TAMIL NADU - 2

6 TELENGALA - 1

7 PUDUCHERRY - -

8 LAKSHADWEEP - -

TOTAL 2 11

Action taken by the Utilities in this regard needs to be informed to CEA and MoP.

10. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR

10.1 The status of implementation of Bus / Line Reactors / Dynamic Compensation

approved in the Standing Committee / SRPC pending for commissioning by the SR

constituents are furnished below:

Entity Bus Name Status REMARKS

KPCL Raichur TPS By June 2015 As identified in the 22nd

Standing

Committee Meeting on Power

System Planning of SR and as

approved in the 4th SRPC Meeting

held on 7th June 2007

KPTCL

Hoody By June 2015

Davanagere Commissioned on

23.03.2015

Nelamangala By June 2015

Talaguppa By June 2015

Guttur Line Reactor By June 2015 Shifted from Hoody


Entity Bus Name

Capacity

in

MVAR

Approve

d in Type Remarks

PGCIL

Vijayawada 2x125

20th

SRPC/

34th

SC

Bus

Likely

commission

ing during

December

2015-March

2016

Nagarjuna Sagar 125

21st

SRPC/

34th

SC

Bus

Narendra 125

21st

SRPC/

34th

SC

Bus

Hyderabad 125 21st SRPC

Gooty 125

22nd

SRPC /

36th

SC

Bus

Hassan 125

36th

SC

Bus

Khammam 125 Bus

Narendra (New) 125 Bus

Trivandrum 125 Bus

Nellore (Existing) 125 Bus

Yelahanka 2x63 Bus

Nellore PS on NPS-

Gooty Line

2x63

(37th

SC) Line

Narendra–Madhugiri

D/C at each end 4x63 Line

APTRANSCO

Vemagiri 80

21st

SRPC/

34th

SC

Bus

Commissio

ned on

05.03.2015

Vemagiri 125

36th

SC

Bus

By Dec

2015 Kurnool 125 Bus

Kalpakka 125 Bus

TSTRANSCO

Mamidipalli 125 Bus

By June

2016

Gajwel 125 Bus

Sankarapalli 125 Bus

Mehboob Nagar 125 Bus

NPCIL

Kaiga 2 x125

Bus

In the 1st

Task Force

Meeting

NPCIL

agreed for

2x125

MVAR


10.2 Dynamic Compensation (Approved in 36th

SC)

Entity Bus Name

SC

MVA

GVA /

KA

Dynamic

Compensation

(STATCOM)

Mechanically

Switched

Compensation

(MVAR) Remarks

Reactor Capacitor

PGCIL

Hyderabad 18.4/

26.5

+ 200 MVAR 2x125 1x125

2015-16 Udumalpet 19.4/

28.0

+ 200 MVAR 2x125 1x125

Trichy 12.5/

18.0

+ 200 MVAR 2x125 1x125

In earlier Meeting, PGCIL had suggested that a regional pool of spare bay

equipment be maintained in view of natural calamities taking place.

11. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION

11.1 Automatic Demand Management Schemes

11.1.1 In line with clause 5.4.2 (d) of the IEGC, Automatic Demand Management Scheme

was to be provided by all the constituents by 1stJanuary 2011.SRLDC & SRPC

Secretariat had pointed out that automated scheme was to be in place to meet

Regulatory requirements.

11.1.2 The following is the status update:

In compliance of Order dated 22nd

February 2014 of CERC in respect of

Petition No. 120/2011, it was learnt that TANTRANSCO had finalized

the scheme and communicated to P&C Wing for implementation. Since

considerable time had lapsed, the scheme needed to be in place at the

earliest.

In the special meeting held on 25.02.2015 TANTRANSCO had

assured that about 100 MW ( 1st stage out of 650 MW) loads

under ADMS would be ensured before 31st March 2015. Balance

quantum would be progressively implemented in 2-3 months. The

logic would take care of sudden withdrawal of wind generation

also. The progress is being followed up in OCC/TCC/ SRPC

Meetings and the Scheme is yet to be implemented.

In the 105th

Meeting of OCC (10.03.2015), KPTCL had informed that

ADMS had been implemented from 1st February 2015

AP & Telangana had informed that the new upgraded SCADA system

was likely to be in place by March 2015 and ADMS would be

implemented within 2-3 months subsequently.


In the Special Meeting held on 22.01.2015 it was suggested that

initially the scheme could be implemented at locations where RT

availability where RTU availability was there and subsequently the

scheme/logic could be fine tuned once the new RTUs are

commissioned. All efforts would be made to put the automated

schemes in place along with new SCADA preferably before 31st

March 2015. The progress is being followed up in OCC/TCC/

SRPC Meetings and the Scheme is yet to be implemented. .

Puducherry had informed that scheme had been finalized and they were in

deliberation with M/s. ALSTOM. .

11.2 Inadequate UFRs and df/dt reliefs

11.2.1 Issue regarding inadequate relief through UFRs and df/dt relays had consistently been

raised by SRLDC & SRPC Secretariat. SRLDC had also reported the issue under

clause 1.5 of IEGC on a number of occasions. SRPC Secretariat had taken up the

matter with Constituents for necessary compliance. On 19th

December 2013,

Hon’ble CERC had issued its Order in respect of Petition No 263/MP/2012. It had

directed that SR constituents identify additional feeders and install UFR and df/dt

relays to ensure relief as decided by SRPC from time to time. SLDCs had also been

directed to map the relays on the SCADA system within three months of issuance of

the Orders.

11.2.2 The following had been agreed in the 26th

Meeting of SRPC:

States would increase SCADA relief visibility to at least 75% by 1st

March 2015. SRLDC would continue monitoring at 10 days interval.

AP, Telangana and Tamil Nadu to implement the balance quantum and

achieve recommended quantum by 1st March 2015.

11.2.3 The following was noted in the Special/OCC Meetings:

In the Special Meeting (22.01.2015) AP & TS had informed that they would

complete the scheme progressively before 22nd

July 2015. Roadmap for

ensuring recommended quantum and status would be monitored in OCC

meetings.

Roadmap and status yet to be furnished.

In the Special Meeting (25.02.2015) TANTRANSCO had agreed to furnish

the list of additional feeders identified to meet the deficit (overlapping) by

1st week of March 2015. Roadmap along with time schedule for

implementation would also be furnished during next meeting of OCC.

TANTRANSCO had identified 568 MW of additional loads for AUFR and

df/dt.

Roadmap for implementation yet to be furnished.


11.3 Low Voltage and installation of UV Relay/High voltage

Following is the status:

KSEB had implemented the scheme.

KPTCL had identified the feeders and approval from Management had

also been received. Scheme would be implemented within 15 days as

informed in the 106th

OCC Meeting held on 10th

April 2015.

Scheme yet to be implemented

TANTRANSCO had furnished list of feeders identified for UV Relay

Scheme. The implementation of the scheme was being undertaken and it

would take 3 to 6 months since tendering process was involved.

Scheme yet to be implemented.

11.4 Restricted Governor Mode of Operation (RGMO)/FGMO of Generating Units &

MVAR Interchange

11.4.1 In the 26th


SLDC to take up the matter with concerned SERCs regarding non-performing

Units in their control area.

Following generating stations were identified as Model Stations for regular

monitoring and improvement of RGMO/FGMO performance:

APGENCO - Vijayawada STPS, TSGENCO – Kothagudem 500 MW unit

KPCL – Raichur TPS (except unit-4), TANGEDCO – North Chennai

Stage-II

KSEB- Idukki HEP, All CGS, JSWEL – Torangallu and UPCL

Other Units would also endeavor to improve their performance

SRLDC had stated that RGMO/FGMO status points should be made available

to SLDC/SRLDC.

11.4.2 In the 106th

meeting of OCC, the RGMO analysis for incident that occurred on

07.04.2015 at 21:01 hrs was discussed. The same is presented at (Annexure-XI). Out

of expected response of about 1,000 MW, the response in SR was observed to be only

243 MW which is a matter of concern.

11.5 Low Voltage Ride Through (LVRT)

11.5.1 The following had been noted in the various Meetings:

There had been 3-4 incidences of wind generation withdrawal of around

1,000 MW in the past two year. This could be on account of non-availability

of LVRT feature which is a matter of great concern to grid security. Special

Meeting of Protection Sub-Group had been held in this regard on 08th

July

2014


TANTRANSCO had informed that the matter regarding provision of LVRT

features was being taken up with the wind developers. In the meeting

(25.02.2015) it was noted that TANGEDCO would verify whether generators

(connected after 15.04.2014) were equipped with LVRT features as mandated

under CEA Regulations and take appropriate action in this regard.

TANGEDCO would revert back on possibility of LVRT features for existing

machines also.

TANGEDCO yet to revert back.

KPTCL had informed that they were viewing the issue with concern since

about 70% of the wind mills in Karnataka Grid may not be equipped with

LVRT feature presently. They would take up the issue with wind developers.

Compliance in this regard could be planned only in a phased manner. Most of

the wind mills (about 95 %) were privately owned and commissioned over a

period of 6 to 8 years. In the meeting (16.01.2015) KPTCL had informed that

note on requirement/need had already been submitted to their Management.

Apprehensions with regard to additional cost implication etc. had been raised.

Status update by KPTCL

In the meeting (22.02.2015) AP & TS were informed about the requirement

and they were to revert back.

AP /TS yet to revert back

SRLDC had filed a Petition before Hon’ble CERC in this regard.

11.5.2 As mentioned in the RoP (25.02.2015) of CERC Petition 420/MP/2014

(Annexure-XII) SRLDC had stated that as per Regulation B (3) of the Central

Electricity Authority (Technical Standards for Connectivity to the Grid)

Regulations, 2007, Low Voltage Ride through (LVRT) is compulsory for

machines installed after 15.4.2014 but for existing wind power generating

stations, LVRT should be mutually discussed. It does not exempt any station from

installing LVRT.

11.5.3 SLDC/STU’s role for Distributed Generated Resources as per Regulation 4(8) of

CEA (Technical Standards for Connectivity of the Distributed Generated

Resources) Regulation 2013, is brought to kind attention:

“The appropriate licensee shall inform the concerned State Transmission

Utility within 30 days of acceptance of application for connectivity of a

generating station to Electricity System operating at voltage level below 33

kV. The concerned State Transmission Utility shall intern inform the State

Load Despatch Centers with details of Installed Capacity, Generators

capabilities, connectivity and likely date of commissioning or date of

commercial operation.”


11.6 Demand Estimation for Operational Purpose (Clause 5.3 of IEGC)

Each SLDC was to create a mechanism and facilities to facilitate on-line demand

estimation of demand for daily operational purpose for each 15 minutes block by

01.01.2011. In this regard, following may kindly be noted as contained in Order dated

19th

December 2013 of Hon’ble CERC in Petition No. 249/250/251/MP/2012:

“We direct all STUs/SLDCs of the Northern Region, Southern Region and

Eastern Region to forecast their demand and make adequate arrangements to

avoid dependence on Unscheduled Interchange for meeting their demand or

for injecting short term surplus power, irrespective of the frequency.”

Load Forecasting tool meeting the regulatory requirement yet to be

developed by all the utilities.

SRLDC/SRPC Secretariat had expressed concern that Regulatory

requirements had not been met since the scheme was to have been put in

place by 01.01.2011.

11.7 Sudden Change in Demand / Frequency Excursion

In earlier Meetings, violation of Clause 5.2 (j) of the IEGC Regulations has been

highlighted. No user is to cause sudden variation in its load by more than 100 MW

without prior intimation to and consent of the RLDC. Similarly no user should reduce

the generating unit output by more than 100 MW without prior intimation to and

consent of the RLDC. Necessary action was sought in respect of demand and

generation management as well as power purchases, so that clause 5.2 (j) of IEGC

Regulations is not violated.

SRLDC/SRPC Secretariat had expressed concern that despite regular follow

up and Special Meetings the Regulatory provisions were not being fully met

and requested for necessary compliance.

11.8 Arranging of interruptible loads in four groups

As per IEGC, to maintain the frequency within stipulated band and also to ensure

network security, interruptible loads are to be arranged in four groups of loads.

This was for the purpose of scheduled power cuts/load shedding, loads for

unscheduled load shedding, loads to be shed through UF relays, df/dt relays and

loads to be shed under any SPS Scheme. These loads are to be grouped in such a

manner that there was no overlapping between different groups of loads.

Existing schemes were not meeting the Regulatory requirement fully and

further action was required in this regard.


11.9 PSS Tuning

11.9.1 The need for PSS tuning of all major generators has been raised by SRLDC on number

of occasions in the recent past keeping in view the sustained oscillations of high mode

and poor damping. In the SRPC Meetings it was noted that in the Meeting taken on

11th

March 2014 to discuss the Task Force Report, CTU had been entrusted the

responsibility of PSS tuning. Keeping in view the observations raised by PGCIL of

not having the necessary expertise in generator/governor technology, CTU had been

suggested to suitably take up the matter with MoP for further directions.

11.9.2 In the 26th

Meeting of SRPC, CTU had assured that they would take up this issue

appropriately.

11.10 TTC / ATC

NRCE has issued operation guidelines for determination of Total Transfer Capability

(TTC), Available Transfer Capability (ATC) and Transmission Reliability Margin

(TRM) for short term horizon (0-3 months) which is available on CEA website.

POSOCO has been advised to assess TTC considering temperature dependent thermal

ratings of the lines / terminal equipments. SRPC Letter dated 15.04.2015 enclosing

NLDC Letter 06.04.2015 regarding certification of line rating / equipment rating for

purpose of adopting seasonal rating is furnished at (Annexure-XIII)

11.11 Sharing the relief for SPS Trip Signals

TSTRANSCO had agreed to provide 52% of total relief of 825 MW, which had been

provided earlier in undivided state. Loads in Veltoor and Hyderabad areas had been

identified and the proposal had been put up to management for approval. Extension

of the relief signal needs to be expedited by TSTRANSCO.

11.12 Scheduling of Simhadri STPS Stage-I

In the 26th

Meeting of SRPC it was noted that necessary exemption from Hon’ble

CERC was needed to be obtained by APSLDC with regard to control area aspects of

Simhadri STPS-I (scheduling issues). In the Special Meeting (22.01.2015) it was

noted that certain amendments in PoC regulations were anticipated.

Hon’ble Commission have now notified CERC (Sharing of Inter State Transmission

Charges and Losses ) (Third Amendment ) Regulations, 2015 which shall come in to

force 1st May 2015. Necessary action needs to be initiated in this regard


11.13 Pending issues of KKNPP

Need for additional reactor at KKNPP switch yard

The MVAR absorption limit is being restricted to 100 MVAR against the capability

up 300 MVAR since as per OEM about 100 MVAR only was the limiter setting.

KKNPP needs to install additional reactors in order to contain the high voltages in

that area keeping in view clause 4.6.1 (b) of IEGC Regulations. The issue was

further deliberated in the Special Meeting held on 07.04.2015 wherein KKNPP

informed that they seek assistance of CTU for studies and would revert back within

two months.

Implementation of auto reclose with 1½ breaker scheme

In the Special Meeting held on 07.04.2015 KKNPP informed that all the necessary

approvals had been received. During the planned shutdown of Unit-1 during end of

June 2015 for six days, the scheme would be implemented.

Pending SCADA inputs to SRLDC

In the Special Meeting held on 07.04.2015, KKNPP informed that all the approvals

had been received and tendering was under progress and it would take another six

months to provide the pending inputs to SRLDC.

Status of SPS (Generation ramping down) during tripping of ATS

KKNPP was requested to relook into the instantaneous requirement as that only

could ensure survival of the unit during tripping of three ATS lines. KKNPP/NPCIL

stated that they would revert back.

Status of SPS (Load Relief by the Constituents) with two units in operation

The issue would be deliberated in the Protection Sub Committee Meeting.

11.14 Other Issues requiring kind attention of SRPC/ TCC

The following issues are being regularly followed up in the Sub-Committees of

SRPC, and merit kind attention:

Coal stock position in a few thermal stations such as Vallur STPS and Raichur

TPS in the region is critical

Nominations for the Study Group of SLDCs from APSLDC and TSSLDC

were awaited. All the other States had furnished the nominations and the

ATC/TTC Studies were held up.


KSEB had requested additional 5 MW power through 110 kV

Manjeshwaram – Konaje feeder for proposed Railway tractions substation

at Uppala. KPTCL could kindly consider the request.

URTDSM (PMU) project in SR was to be implemented in 24 months from

date of award. PGCIL had informed Type Test had been completed and

PMUs would be dispatched to the locations from May 2015 onwards.

Schedule of commissioning to be finalized by CTU.

Phase-I & Phase-II activities identified in Protection Audit needs to be

completed. Progress of the implementation needs to be submitted to

SRPC/SRLDC in a time bound manner. In RoP of Hon’ble CERC (date of

Hearing 15.01.2015) with regard to TN petition No. 374/ MP/2014, TN &

other SR constituents had been directed to submit implementation of

protection audit recommendations in their respective states by 31st March

2015.

Reactive Power Planning including at distribution level needs to be

submitted to CEA with a copy to SRPC Secretariat.

KPTCL had informed that a scheme of 1,219 MVAR had been

finalized and five transmission zones had already initiated the tender

process for capacitor banks.

TSSPDCL had informed that 249 x2 MVAR Capacitors and 179 x5

MVAR Capacitors had been planned at 11 kV and 33 kV levels

respectively. TSNPDCL had informed that they had also firmed up

the requirements and they would furnish the details within 10 days.

APEPDCL had informed that 72x1 MVAR, 103 x 2MVAR and 30 x

2 MVAR (separate scheme) were planned. APSPDCL had informed

that 43 MVAR Capacitors were planned during April – June 2015.

TANTRANSCO had informed that for 2014-15, they had planned

installing 34 units (2.4 MVAR) capacitor banks at 11 kV level and 16

units (2.4 MVAR) capacitor bank at 22 kV level. Time schedule for

completion of installation of these capacitor banks was six months. 7

Nos. of 168 MVAR capacitor banks at 110 kV level in Coimbatore

area had been planned and approval from their Board had been

received. Around 755 MVAR of capacitors at distribution level had

been commissioned out of 1,005 MVAR capacitors planned.

Information regarding tripping details with relay indications was needed to

be furnished in a timely manner.

Information regarding Cyber Security was to be furnished to Chief Engineer,

DPD, CEA, New Delhi. Report on Physical Security, other Mock Drills for

CMP, Mock Drill for Black Start Restoration is to be furnished to Chief

Engineer, DMLF, CEA, New Delhi. Copy of the report is to be sent to

SRPC Secretariat by e-mail.

NTPC, NHPC & PGCIL had been designated as CERTs (Computer

Emergency Response Teams) for Thermal, Hydro and Transmission

respectively. Director (IT), CEA had been nominated as Chief

Information Security Officer (CISO) for MoP. Critical issues were


highlighted during the Presentation. As an initial step, all the

utilities were requested to nominate one Chief Information Security

Officer (CISO) for Cyber Security at senior level.

APTRANSCO, TANTRANSCO, TANGEDCO, KSEB, NPCIL,

KPCL, NTECL, NLC, SRLDC, KPTCL, TSTRANSCO &

TSGENCO had submitted the CISO Nominations. Others utilities

are requested to kindly furnish the same at the earliest.

Procedure for restoration of remotely controlled sub stations of PGCIL along

with the contact no. of the person who would take care during emergency

conditions needs to be developed and furnished to SRLDC.

CEA had requested certification of CoD from RPCs. Communication dated

30.01.2015 received from CEA is at (Annexure-XIV) All the utilities are

requested to kindly furnish the details of CoD for further needful.

CEA vide letter dated 27.02.2015 had requested for hourly figures of

scheduled / unscheduled power cuts / load shedding to be furnished by the

States / UTs in the first week of the following month. Constituents are

requested to furnish the information in a timely manner.

At HVDC Bhadravati , ICT (400/220kv , 315MVA) was commissioned on

17.03.15, and connection for supply for auxiliary of the both HVDC poles is

being utilized w.e.f. 02.04.15.

Transmission elements outage planning to be carried out in a coordinated

manner and shutdown requests to be received by 3rd

of each month for the

next month. Outages for the same months were being requested by the

constituents which need to be avoided.

Tap changing to 400 kV level to be carried out at North Chennai TPS,

Krishnapatnam JV and Kaiga GS.

Auto Reclose feature enabling for 400 kV Ramagundam – Chandrapur lines,

400 kV Kaiga – Guttur lines, 400 kV Mettur – Arasur lines, 230 kV Neyveli

– Villianur lines and Neyveli – Bahoor lines.

Operation of Nagarjuna Sagar in pump mode. APGENCO and TSGENCO

to ensure the needful.

Operation of Srisailam and Kadamparai (Unit 3&4) in pump mode.

TSGENCO and TANGEDCO to rectify the defects for enabling pump mode

operation.

TSGENCO and TSTRANSCO to coordinate with PGCIL for feasibility of

installation of reactor at Srisailam.

12. REVIEW OF PERFORMANCE OF ULDC SCHEME

The issue is being followed up in the monthly Meetings of OCC. Following are the

actionable points in this regard:

Status of data, voice, internet communication and pending field inputs as

discussed in the 106th

OCC is enclosed as (Annexure-XV) .


Standby data channels from 400 kV S/S (SR1 & SR2) not made through. 11

DCPC communication channels were to be established by SR-I and SR-II.

Talcher-II data to be integrated in new SCADA system at SRLDC.

Pending field inputs from KKNPP, MAPS and Kaiga GS to be ensured.

Pending field inputs from UPCIL stations to be ensured

Status review of new SCADA implementation.

Dedicated hot line facility from APSLDC.

Special Meetings were conducted on 13.02.2015 and 17.03.2015 to address

the difficulties being faced by SRLDC in real time operation due to non

availability of no. of data channels.

SCADA validation with SLDCs and ISGS between 10:00 hrs to 12:00 hrs.

13. TRIPPING DETAILS/ DETAILS OF PENDING REMEDIAL MEASURES

DISCUSSED AND FINALIZED IN PCC

SRLDC has been bringing to attention that all users, STUU/SLDC and CTU shall send

information/data including disturbance recorder/sequential event recorder output to

SRLDC within 24 hours for purpose of analysis. However, in several instances the

required data is not being received as per provisions of Regulations. Further, Grid

incidents are being analyzed and discussed in the monthly Meetings of Protection Sub

Committee. A number of visits by the Members of the Sub Group to analyze

major/recurring grid incidents had taken place. Remedial measures are to be complied

with in accordance with the discussions in the Protection Sub Committee.

14 S3 REGION TO BE FORMED BY BIFURCATING S2 AND ATC TO BE

CALCULATED FOR S2-S3 REGION BY FOLLOWING THE N-1 CONDITION

IN 400 kV UDUMALPET – PALAKKAD D/C LINES

14.1 The following had been noted in the 26th

Meeting of SRPC:

TANTRANSCO had suggested that S3 comprising of Kerala be carved out

keeping in view Grid security and overloading of 400 kV Udumalpet –

Palakkad D/C lines.

PGCIL had noted that in similar instances, separate areas had been identified

and the matter could be studied.

It was agreed that this issue also would be deliberated in the Study Committee

Meeting with the participation of NLDC, CTU etc.

14.2 Subsequently, a Meeting was held on 29th

December 2014. Record Notes of the

meeting is available at www.srpc.kar.nic.in/website/2015/meetings/special/mstudy-

group29-12-14m.pdf

http://www.srpc.kar.nic.in/website/2015/meetings/special/mstudy-group29-12-14m.pdf

http://www.srpc.kar.nic.in/website/2015/meetings/special/mstudy-group29-12-14m.pdf


15. ITEMS DISCUSSED IN THE MEETING OF COMMERCIAL SUB

COMMITTEE

The following items discussed in the 27th

Meeting of Commercial Sub Committee of

SRPC need to be complied with:

APPCC needed to open an LC for Rs 69,31,199 towards delayed payment of

deviation charges.

Tome drift statements were to be sent by all stations before 6th April 2015.

However, the same is awaited from several of the constituents.

Constituents had agreed to furnish details of the Nodal Office for SEM data

coordination by 02nd April 2015. SRLDC is yet to receive the details from

some of the utilities.

16. REIMBURSEMENT OF SRPC EXPENDITURE

16.1 In the 25th

Meeting of SRPC held on 26th

July 2014, following had been noted:

As per the Andhra Pradesh Reorganization Act 2014, on and from the appointed

day, there shall be formed a new State to be known as the State of Telangana.

Ministry of Home Affairs vide Notification dated 4th

March 2014 had notified

the appointed day as 2nd

June 2014. Accordingly, the new State of Telangana

was formed on 2nd

June 2014.

As per Resolution of Ministry of Power with respect to establishment of SRPC,

Membership would be from each of the States in the Region - the State

Generating Company, State Transmission Utility (STU), State Load Despatch

Centre (SLDC), one of the State owned distribution companies as nominated by

the State Government and one distribution company by alphabetical rotation out

of the private distribution companies functioning in the region.

SRPC Secretariat vide letter dated 10th

June 2014 had taken up with CEA

regarding amendment in above referred Resolution of MoP.

Formal notification of MoP with regard to Telangana as Member was awaited.

With inclusion of Telangana, the sharing of expenditure would undergo revision

and the same would be communicated in due course.

16.2 Since the formal notification is awaited it is proposed that the sharing of expenditure

for the year 2014- 15 be revised including Members from TSTRANSCO & TSGENCO

(APTRANSCO, APGENCO & TSSPDCL already considered). Sharing of expenditure

for the year 2014-15 would thus be reworked. For the year 2015-16, APSPDCL &

TSNPDCL would be the Members in respect of Andhra Pradesh and Telangana

distribution companies. Accordingly, sharing of expenditure for the year 2015-16

would be computed.


A FOR INFORMATION OF TCC/ SRPC

1. GRID OPERATION

1.1 Grid events/highlights during December 2014

Unit- I (1,000 MW) at KKNPP declared on COD from 31st December 2014 by

NPCIL.

Unit- I (600 MW) at Coastal Energen was declared on COD from 23rd

December

2014.

Unit- II (800 MW) at SDSPP Krishnapatnam JV was synchronized for the first

time on 16.12.2014.

Unit- IV at SEPL (150 MW) was synchronized for the first time on 30.12.2014.

Unit- I at TPCIL (660 MW) was synchronized for the first time on 22.12.2014.

Andhra Pradesh, Telangana, Karnataka, Kerala & Tamil Nadu imported 259 MU,

187 MU, 8 MU, 0.725 MU & 467 MU respectively inter-regionally through

bilateral exchanges.

Utilities located in Andhra Pradesh, Telangana, Karnataka, Kerala & Tamil Nadu

imported 75 MU, 77 MU, 50 MU, 162 MU & 38 MU respectively through Power

Exchange.

Utilities located in Andhra Pradesh,Telangana, Karnataka, Kerala, SEPL& MEPL

exported 41 MU, 31 MU, 162 MU, 3 MU, 20 MU & 30 MU respectively through

Power Exchange.

Andhra Pradesh, Telangana, Kerala & Tamil Nadu imported 353 MU, 304 MU, 94

MU & 33 MU intra-regionally.

Wind mills of capacity 1.5 MW were added in Tamil Nadu.

1.2 Grid events/highlights during January 2015


157MU, 9 MU, 7 MU & 466 MU respectively inter-regionally through bilateral

exchanges.



Exchange.

Utilities located in Andhra Pradesh, Telangana, Karnataka, Kerala, SEPL& MEPL

exported 57 MU, 27 MU, 147 MU, 2 MU, 8 MU & 23 MU respectively through

Power Exchange.

Andhra Pradesh, Telangana, Kerala & Tamil Nadu imported 289 MU, 307 MU,

219 MU & 261 MU intra-regionally.

Wind mills of capacity 14.2 MW were added in Tamil Nadu.

1.3 Grid events/highlights during February 2015


178 MU, 9.44 MU, 1.29 MU & 425 MU respectively inter-regionally through





Exchange.


exported 38 MU, 29 MU, 165 MU, 0.72 MU, 4.85 MU & 9.16 MU respectively

through Power Exchange.

Andhra Pradesh, Telangana, Kerala & Tamil Nadu imported 273 MU, 266 MU,

210 MU & 211 MU intra-regionally.

The following communication elements of PGCIL have been successfully put into

in continuous service from 00:00 hrs on 01-07-14 with successful transfer of voice

and data to SRLDC

a) Neyveli TS II Exp-Pugalur OPGW communication links

b) Neyveli TS II Exp- Neyveli TS II OPGW communication links

c) Neyveli TS II- Pondy OPGW communication links

1.4 Grid events/highlights during March 2015

Andhra Pradesh, Telangana, Karnataka, Kerala& Tamil Nadu imported 146 MU,

158 MU, 10.75 MU, 151 MU & 474 MU respectively inter-regionally through



imported 83 MU, 160 MU, 44 MU, 8.3 MU & 72 MU respectively through Power

Exchange.


exported 28.80 MU, 24.27 MU, 163 MU, 4 MU, 22.21 MU & 5.79MU respectively

through Power Exchange.

Andhra Pradesh, Telangana, Kerala & Tamil Nadu imported 307 MU, 417 MU, 99

MU & 304 MU intra-regionally.

Andhra Pradesh met demand of 7100 MW on 17.03.2015 which was maximum till

date. Andhra Pradesh met per day energy consumption of 153.7 MU on 26.03.2015

which was maximum till date.

Telangana met demand of 6914 MW on 28.03.2015 which was maximum till date.

Telangana met per day energy consumption of 154.10 MU on 26.03.2015 which

was maximum till date.

Karnataka met demand of 9790 MW on 26.03.2015 which was maximum till date.

Karnataka met per day energy consumption of 211.7 MU on 26.03.2015 which was

maximum till date.

Kerala met demand of 3602 MW on 26.03.2015 which was maximum till date.

Kerala met per day energy consumption of 70.98 MU 26.03.2015 which was

maximum till date.

Southern Region met demand 38090 MW on 27.03.2015 which was maximum till

date and consumption touched 892.7MU/day on 26.03.2015 which was maximum

till date .

Guttur Bus reactor commissioned on 23.03.2015.

Line reactors of Vijaywada-Nellore lines were commissioned on 14.03.2015.

Nagapattinam PS (GIS) was Commissioned on 31.03.2015.


765 kV Kurnool-Thiruvalam D/C lines were charged at 765kV lines on 20.03.2015.

The following OPGW communication links along with the associated

communication equipment were declared under commercial operation from

30.03.2015.

1. 400 kV Neyveli TS-II 400 Kv Neyvelli TS-I Expn

2. Tuticorin Pooling Station – Madurai S/s

3. Madurai Sub LDC (TNEB) – Madurai 230kV (TNEB) –Madurai (PG)

4. 400kV Pugalur (PG) – Trichy (TNEB) – Trichy (PG)

5. 230kV Tanjore (TNEB) – 400kV Trichy (TNEB)

6. 230kV Thiruvarur (TNEB) - 230kV Tanjore (TNEB)

7. 400kV Hassan (PG) – Nelmangala (KPTCL)

8. 400kV Narendra –Davangere

9. Kolar – Thiruvalam

10. Madurai - Trichy

11. Madurai – Tirunalveli

12. Tirunalveli – Trivendrum

13. Sriperambadur - Kalivindapattu

14. Udumalpet – Arasur

15. Salem – Udumalpet

16. Nagapattinam –Trichy

17. Nagapattinam - Neyvelli TS-I Expn

1.5 Installation of Shunt Capacitors

The progress of installation of capacitors by the constituents during the year

2014-15 is furnished in the Table below:

(Figures in MVAR)

State Requirement

for 2014-15

Installed during the year 2014-

15 (till 31st March 2015)

Andhra Pradesh 26.20 0.00

Karnataka 56.31 0.00

Kerala 10.00 0.00

Tamil Nadu 122.40 0.00

Installation of required capacitors works is sought to be completed early.

1.6. DEMAND VARIATION (Peak Vs Off-peak)

Issue regarding large variation between minimum and maximum demands has been

under the consideration of TCC/SRPC. The issue is also being discussed in the monthly

Meetings of OCC. Following was observed with regard to the period from December

2014 to March 2015:

Description

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala

Tamil

Nadu Puducherry

Southern

Region

December 2014

Highest 26.18 32.60 37.46 46.67 36.34 46.32 25.71

Date 28th

(Fri) 5th

(Fri) 12th

(Wed) 1st (Mon) 22

nd (Sat) 31

st (Mon) 19

th (Wed)

Lowest 13.96 17.04 19.31 34.71 18.19 18.77 16.98

Date 5th

(Fri) 21st

(Fri) 3rd

(Wed) 25th

(Tue) 14th

(Fri) 21st (Fri) 25

th (Tue)

Average 18.12 25.85 27.59 41.46 25.84 35.48 21.78


January 2015

Highest 29.25 35.49 29.45 47.49 32.05 48.53 27.38

Date 15th

(Thu) 15th

(Thu) 27th

(Tue) 14th

(Wed) 19th

(Mon) 19th

(Mon) 15th

(Thu)

Lowest 13.97 13.12 20.18 34.37 17.72 26.19 15.61

Date 6th

(Tue) 1st(Thu) 7

th(Wed) 11

th(Sun) 4

th(Sun) 4

th(Sun) 31

st(Sat)

Average 21.13 28.89 24.36 41.80 25.12 36.95 21.36

February 2015

Highest 26.82 41.92 26.35 42.12 29.25 38.82 24.29

Date 17th

(Tue) 10th

(Tue) 3rd

(Tue) 9th

(Mon) 2nd

(Mon) 16th

(Mon) 21st(Sat)

Lowest 12.31 14.24 12.47 33.57 14.01 23.93 8.04

Date 12th

(Thu) 18th

(Wed) 28th

(Sat) 28th

(Sat) 27th

(Fri) 22nd

(Sun) 28th

(Sat)

Average 17.66 22.26 20.34 38.49 21.40 34.17 16.62

Note: Highest & lowest figures for the month have been computed based on the daily values.

1.7. FREQUENCY OF OPERATION OF SOUTHERN GRID

The frequency of operation of the Southern Grid for the period under review is

furnished below:

Month

Percentage of time when frequency (Hz) was

Month

Avg.

freq. Less

than

49.5

49.5

to

49.7

49.7

to

49.9

49.9

to

50.0

50.0

to

50.05

50.05

to

50.20

More

than

50.20

Within

IEGC

range

49.9 to

50.05

December 2014 0.00 1.35 24.61 30.59 17.64 23.25 2.56 48.23 49.98

January 2015 0.00 0.79 19.29 34.78 19.45 22.95 2.75 54.24 50.00

February 2015 0.00 0.29 13.88 37.68 23.71 23.31 1.13 61.39 50.00

March 2015 0.00 0.54 17.68 37.73 21.13 21.50 1.42 58.86 49.99

During the period under review, caution / violation messages (Annexure-XVI) were

issued to the constituents by SRLDC. Matter regarding overdrawal at low frequency by

some constituents is being regularly deliberated in the OCC forum. Utilities are

requested to kindly adhere to Regulations in this regard.

2. ACCOUNTING OF COASTAL ENERGEN INJECTION / DRAWAL

In the 27th


March 2015,

the following had been noted:

SRLDC had informed that injection of Coastal Energen was computed

using Madurai end of 400 kV Coastal Energen-Madurai line and Coastal

end of 400 kV NTPL - Coastal line as per point no 7.4 of Minutes of 25th


Commercial Committee Meeting. In view of the LILO of 400 kV Coastal

Energen-Madurai line and 400kV NTPL-Madurai lines at newly

commissioned Tuticorin Pooling Station, metering points for computing the

injection of Coastal Energen needed to be reviewed.

In the 25th

Meeting, energy accounting of startup power drawal by Coastal

Energen based on SEMs at Madurai end on Madurai – Coastal line and

Coastal end on Coastal – NTPL line had been agreed.

Unit-1 (600 MW) of Coastal Energen was declared under commercial

operation.

Connectivity originally granted to Coastal Energen is at Tuticorin Pooling

station (dedicated line from Coastal Energen to Tuticorin Pooling Station).

In view of Commercial Operation of Coastal Energen Unit, accounting of

injection / drawal by Coastal Energen needed to be carried out based on far

end meters.

Accordingly, accounting of injection / drawal by Coastal Energen would

be based on SEM at Tuticorin Pooling Station end on Coastal Energen-

Tuticorin Pooling Station line and SEM at NTPL end on Coastal Energen –

NTPL line

After deliberations, it was agreed that accounting of Coastal Energen

injection/drawl would be based on the SEMs at Tuticorin PS end and

NTPL end. SRLDC would implement the same in the weekly accounting

w.e.f. 23rd

March 2015 till commissioning of dedicated lines from Coastal

Energen to Tuticorin Pooling Station.

After commissioning of dedicated lines from Coastal Energen to Tuticorin

Pooling Station, SEMs at the pooling stations would be used for energy

accounting of Coastal Energen.

3. INSTALLATION OF SEMs ON BOTH ENDS ( CHARGING CLEARENCE FOR

NEW TRANSMISSION ELEMENTS).

In the 27th


March 2015, the

following had been noted:

SRTS-II had informed that SRLDC was insisting installation of SEMs on

both ends of line for charging clearance. For charging clearance, provisions

of CEA (Installation and Operation of Meters) Regulations 2006 & 2010

could only be insisted. Additional requirement of SEMs would be provided

subsequently.

Commercial Sub-Committee had observed that for charging clearance,

SRLDC needed to insist only on Regulatory requirements. However,

POWERGRID should consider provision of SEMs on both ends of line at

planning stage itself.

SRLDC had agreed for charging clearance for new elements with respect to

adherence of provisions of CEA (Installation and Operation of Meters)

Regulations 2006 & 2010 and amendments thereof.


4. AMR IMPLEMENTATION IN SOUTHERN REGION

Presentation made by SRTS- II in OCC & Commercial Sub-Committee Meetings of SRPC

regarding implementation of AMR is furnished at (Annexure-XVII)

B ANY OTHER ITEM WITH THE PERMISSION OF THE CHAIR

C DATE & VENUE OF THE NEXT TCC / SRPC MEETING

As per Roster approved in the 25th

Meeting of SRPC, NTPC is to host the 28th

Meeting

of SRPC.

*********

1


BENGALURU

2nd

SUPPLEMENTARY AGENDA NOTES FOR THE 26th

MEETING OF

TCC & 27th

MEETING OF SRPC TO BE HELD AT HYDERABAD ON 11th

& 12th

MAY 2015

I. APTRANSCO vide Petition No.95/MP/2015 had approached Hon’ble CERC seeking

extension of time for implementing the Commission’s Order dated 19th December 2013

in respect of Petition No.146/MP/2013.

Hon’ble CERC heard this Petition on 9th

April 2015 and has issued Order dated 27th

April 2015. As per this Order, SRPC has been directed to monitor the status of

completion of works relating to Protection Audit remarks in respect of 7 Nos. 400 kV

substations and 11 Nos. 220 kV substations of APTRANSCO and Protection Audit

remarks in PCSC Meetings.

Periodic Protection Audit in Southern Region is also to be coordinated after

deliberations in SRPC. Bimonthly reports are to be submitted to Hon’ble CERC.

In this regard, the modalities for carrying out periodic Protection Audit in Southern

Region are to be discussed.

II As deliberated and agreed in the OCC/PCSC Meetings, TSTRANSCO is to share the

relief for SPS trip signal. In this regard, copy of letter dated 29th

April 2015 from

TSTRANCO is enclosed as Annexure-A. It has been stated that feasibility of extension

of DTPC signal to the following locations in addition to Veltoor 400 kV SS in TS grid to

provide required load relief may be examined:

i) 400/220 kV Gajwel SS

ii) 220 kV Budidampadu SS

iii) 220 kV RSS

It is also stated that PGCIL have informed that extension of DTPC signal to any of the

location can be taken up only after receipt of instructions from SRPC/SRLDC.

III KSEBL vide letter dated 4th

May 2015 (Annexure-B) have proposed the following

Agenda Items for discussion:

1) IEGC Violation message issued by SRLDC

SRLDC is issuing violation messages against zero crossing of deviation. However,

SRLDC has been insisting that deviation correction has to be done as per Area

Control Error (ACE). As per Regulations, ACE has not been specified for zero

crossing. RLDC/POSOCO may approach Hon’ble Commission for review of

2

Regulation before taking any suo-motu action.

2) Upcoming Transmission Systems / Transmission Constraints

It is stated that the major beneficiary of lines such as 400 kV North Trichur-

Kozhikode and Kozhikode-Mylatti-Mangalore is KSEB Ltd. It has been suggested

that construction may be done by KSEBL on its own. The existing RoW may be

utilized wherever required with multi-voltage multi-circuit configuration by KSEBL

without affecting feeding to existing 220/110 kV substations.

As regards, Mysore-Kozhikode link it has been stated that the delay is in providing

ICTs at Areakode. In case the line works can be completed by September 2015, the

substation can be commissioned early by shifting ICTs from some other location.

Possibility of assigning Udupi-Kasaragode-Kozhikode transmission system to

POWERGRID under urgency clause has been proposed to be examined.

3) Including already completed/ongoing Protection Audit works recommended by

Protection Audit team of SRPC for PSDF fund

It has been stated that earlier all constituents had been requested not to link financial

assistance from PSDF for implementation of Protection Audit Recommendations.

However, NLDC vide letter dated 7th

April 2015 has informed that schemes for which

LOAs have already been placed are not been considered for funding under PSDF.

Further, LOA should be placed only after approval of the scheme by Monitoring

Committee of PSDF. Intervention of SRPC forum has been sought to consider the

claim requested.

4) Pending Payables/receivables between Beneficiary States in SR

It is stated that an amount of Rs.12,37,62,424 is receivable to KSEB as on 31st

January 2015. KSEBL is of the view that a decision in the SRPC Meeting has to be

arrived regarding consensus on such long pending issues.

5) Outstanding Payment from APPCC

It is stated that as on date the net receivable to KSEBL is Rs.15,61,13,679.

6) Outstanding Payment between SR & WR

It is stated that after 26th

SPRC Meeting, no funds have been transferred to SRTS

from WRTS. The details of receivables to KSEBL from GEB, MSEDCL, CSEB and

MPSEB have also been mentioned.

7) Revising the Transmission Reliability Margin between S1 and S2

The matter regarding revision of TRM between NEW Grid and SR Grid as 500 MW

as proposed by PGCIL has been proposed for discussion. It is also suggested that the

same methodology be adopted for determining TRM between all interconnecting

areas including S1-S2 areas. In case the methodology submitted by CTU is accepted,

3

the TRM between S1-S2 could be reduced to 158 MW.

8) Augmentation of Talcher-II Transmission System

It is stated that all utilities in SR would benefit with the early commissioning of

Talcher-II Transmission System. Considering the above, implementation of Talcher-

II Transmission System has been proposed to be discussed.

9) Early commissioning of downstream system of 765 kV Raichur-Sholapur S/C

lines for enhancing the import capability

It is stated that proposed lines such as Gooty-Madhugiri and Madhugiri-Yelahanka

are facing severe RoW issues. Vijayawada-Nellore link is also facing severe RoW

problem. It has been stated that PGCIL be directed to speed up the implementation of

associated transmission system to enhance the TTC. Further, PGCIL has charged

Kurnool-Thiruvalam 765 kV DC line at 400 kV on 27th

November 2014. The line

was expected to be charged at 765 kV level by March 2015. The progress of the same

has been proposed to be discussed.

10) Approach being taken by CTU for blocking the Transmission Capacity for the

Customers who have availed LTA without identifying the beneficiaries

It is stated that inconsistent approach has been adopted by CTU for blocking

transmission capacity for customers who have availed LTA without identifying the

beneficiaries. It has been suggested that CTU take a consistent approach that though

LTA can be applied based on target region, availing or booking of corridor for such

LTA applicants can be made only after signing of PPA with firm beneficiaries.

Further, LTA applicants earlier applied based on target region may be given

preference over new LTA applicants with firm PPA when the target region LTA

customer approaches CTU with firm PPA.

11) Execution of the Transmission System for Ultra Mega Solar Power Park in

Anantpur Distt., Andhra Pradesh

It has been stated that the proposed transmission system envisaged for evacuation of

solar power from 1,500 MW Solar Park in Anantpur District may not be implemented

as ISTS since 90% of the share from the project is allotted to AP. Further, since solar

power is infirm the possibility of flowing of 10% power into the grid continuously is

very rare. Further correct estimates for the total scheme for evacuation and relevant

cost implication and commercial aspects be discussed in SRPC forum and Standing

Committee. If at all, the system is to be developed as ISTS the cost of the

infrastructure be borne by the beneficiaries of the project and not charged from other

utilities. Alternatively, CTU may recover the cost through funding from Green

Energy Fund or PSDF.

4

12) Status of upcoming links having impact on S1-S2

Status of transmission links having impact on relieving S1-S2 constraints has been

proposed to be discussed.

13) Formation of Separate Control Region for Chennai & Krishnapattnam Areas

and for Hiriyur area.

It has been proposed to create a New Control Area incorporating North Chennai-II,

Vallur and other generation in Chennai area and Chennai loads. Separate control area

has also been sought to be created for injection at Krishnapattnam with corresponding

loads. Further, it is mentioned that Yeramarus injection without complete ATS would

increase the loading at Hiriyur area. This would affect the drawal from Raichur.

Hence it has been proposed to form these above two control areas also at the earliest

so that other control areas are not adversely affected due to skewed load generation

balance.

*****

southern regional power committee -...

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