SOUTHERN REGIONAL POWER COMMITTEE - Karnataka · 1.1 The 26thMeeting of Southern Regional Power Committee was held at Visakhapatnam ... Chairman, TANTRANSCO Shri D. Prabhakar Rao,

भारत सरकार

GOVERNMENT OF INDIA

विद्युत मंत्रालय

MINISTRY OF POWER

कें द्रीय विद्युत प्राविकरण

CENTRAL ELECTRICITY AUTHORITY

दविण िते्रीय विद्यतु सवमवत SOUTHERN REGIONAL POWER COMMITTEE

छब्बीसवीीं बैठक की कार्यवतृ

MINUTES OF THE 26TH MEETING

बेंगलूरु BENGALURU

Minutes of the 26th Meeting of SRPC held on 20th December 2014 1 of 73

CONTENTS

1. INTRODUCTION ............................................................................................................................... 3

2. CONFIRMATION OF THE MINUTES OF 25th

MEETING OF SRPC ..................................... 4

3. UPCOMING TRANSMISSION SYSTEM ..................................................................................... 4

4. RANSMISSION LINES APPROVED IN 37th

MEETING OF SCPSPSR .............................. 31

5. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE& UMPP .............................. 32

6. NEW PROJECTS OF STATE SECTOR & IPP ........................................................................... 38

7. COAL STOCK POSITION IN THERMAL STATIONS OF SOUTHERN REGION .......... 39

8. SIMHADRI STPS – SCHEDULES FOR 12-10-2014 TO 25-10-2014 ..................................... 41

9. EMERGENCY RESTORATION SYSTEM (ERS) ..................................................................... 43

10. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR......................... 44

11. STUDY GROUP OF SLDCs TO ASSESS TTC/ATC AND OPERATIONAL

PLANNING ........................................................................................................................................ 47

12. SEMs ON ALL FEEDERS FOR SECTIONAL LOSSES ........................................................... 48

13. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION ........................................... 49

14. REVIEW OF PERFORMANCE OF ULDC SCHEME ............................................................... 57

15. PENDING ARREARS PAYMENT BETWEEN BENEFICIARY STATES IN SR ............... 59

16. OUTSTANDING DUES BETWEEN WR & SR ......................................................................... 60

17. UNIFORM RATE OF CHANGE OF FREQUENCY RELIEF SCHEME ............................... 60

(df/dt) TO BE ADOPTED THROUGHOUT THE COUNTRY ................................................. 60

18. SPS FOR OVERLOADING OF 400 kV KOLAR – HOSUR LINES ....................................... 61

19. DETAILS OF PENDING REMEDIAL MEASURES DISCUSSED AND FINALIZED

IN PCC ................................................................................................................................................ 61

20. WHEELING CHARGES PAYABLE BY GOA TO KARNATAKA ....................................... 62

21. UTILIZATION OF TERTIARY WINDING OF ICTS FOR AUXILIARY POWER

SUPPLY IN SUBSTATIONS ......................................................................................................... 62

22 PROCUREMENT OF 500 MVA ICT AS SPARE INSTEAD OF 315 MVA ICT

APPROVED UNDER RAMAGUNDAM TRANSMISSION SYSTEM .................................. 62

23. PROCUREMENT OF 3x125 MVAR REACTORS INSTEAD OF 3 x 50 MVAR

REACTORS APPROVED UNDER RAMAGUNDAM TRANSMISSION SYSTEM .......... 63

24. CONVERTING FIXED LINE REACTORS INTO SWITCHABLE LINE REACTORS

IN OVER COMPENSATED LINES. ............................................................................................. 63

25. CERC ORDER ON UPCL POWER EVACUATION ISSUE .................................................... 64


26. RE-CONSTITUTION OF THE VALIDATION COMMITTEE UNDER REGULATION

7(1)(g) (SHARING OF INTER STATE TRANSMISSION CHARGES AND LOSSES)

REGULATIONS, 2010..................................................................................................................... 64

27. UTILIZATION OF PSDF TO DEVELOP INTER- STATE TRANSMISSION SYSTEM

TO RELIEVE TRANSMISSION CONSTRAINTS..................................................................... 64

28. EARLY COMMISSIONING OF 765 kV VEMAGIRI-KHAMMAM-HYDERABAD-

WARDHA TRANSMISSION SYSTEM FOR THE ENHANCEMENT OF INTER

REGIONAL TRANSMISSION CAPACITY BETWEEN NEW GRID AND SR. ................. 65

29. PUBLISHING THE RESULTS OF SYSTEM STUDIES BY CTU IN COMPLIANCE

WITH REGULATION 20 OF THE CERC (GRANT OF CONNECTIVITY, LONG

TERM AND MEDIUM TERM OPEN ACCESS) REGULATIONS, 2009. ............................ 65

30. DIFFERENCE IN COMPUTATION OF CAPACITY CHARGES OF NTPC

STATIONS AS PER CERC REGULATIONS (2014-19) .................................................... 66

31. KPTCL DENYING NOC FOR OPEN ACCESS FOR POWER CONTRACTED FROM

UDUPI POWER CORPORATION LTD. ...................................................................................... 67

32. DOUBLING OF 110 KV KONAJE-MANJESHWARAM S/C FEEDER ................................ 67

33. PROVISION OF ADDITIONAL SPACE IN SRPC SECRETARIAT / OTHER CIVIL

WORKS .............................................................................................................................................. 67

34. 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 .............................................................. 68

35. GRID OPERATION .......................................................................................................................... 68

36. DEMAND VARIATION (Peak Vs Off-peak) .............................................................................. 69

37. FREQUENCY OF OPERATION OF SOUTHERN GRID ......................................................... 71

38. URTDSM (PMU) PROJECT IN SOUTHERN REGION ........................................................... 71

39. DRAWAL POINTS OF COASTAL ENERGEN ......................................................................... 71

40. PAYMENT OF TRANSMISSION CHARGES & OPENING OF LC FOR DRAWAL OF

START UP POWER DURING COMMSSIOING PERIOD BY GENERATING

STATIONS ......................................................................................................................................... 72

41. AUDITING OF ACCOUNT - ANNUAL SUBSCRIPTION FOR CONDUCTING

VARIOUS COMMITTEE MEETINGS OF SRPC ...................................................................... 72

42. DATE & VENUE OF THE NEXT SRPC MEETING ................................................................. 73

43. VOTE OF THANKS/PLACING ON RECORD CONTRIBUTIONS ....................................... 73


SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

MINUTES OF THE 26th

MEETING OF SRPC HELD AT

VISAKHAPATNAM ON 20th

DECEMBER 2014

1. INTRODUCTION

1.1 The 26th

Meeting of Southern Regional Power Committee was held at Visakhapatnam

on 20th

December 2014. The list of participants is furnished at Annexure-I.

1.2 Shri R.P.Sasmal, Director (Operations), PGCIL welcomed all Members to the 26th

Meeting of SRPC. He stated that it was a great pleasure hosting the SRPC Meeting at

Visakhapatnam. He thanked all constituents for the continued support and confidence

reposed in PGCIL. He also informed that on 10th

December 2014, Government of India

had issued a Circular for implementing the much awaited 6,000 MW Raigarh –

Pugalur HVDC project by PGCIL. He hoped that in this Meeting, SRPC would look

into the problems being faced in execution of transmission schemes. Transmission

system was required to be implemented, keeping in view anticipated growth for the

next 10 to 15 years. In the recent past there had been substantial improvement in the

SR transmission system especially after synchronization with NEW grid.

1.3 Shri S.R.Bhat, Member Secretary, SRPC welcomed all the Members and delegates to

the Meeting. He extended a special welcome to Shri G.Kumar Naik, Chairperson,

SRPC & MD, KPTCL. He also thanked Shri R.P.Sasmal, Director (Operations),

PGCIL and the entire team of PGCIL for the excellent arrangements for the conduct of

the Meeting.

1.4 Shri G.Kumar Naik, Chairperson, SRPC& MD, KPTCL welcomed all the Members to

the Meeting and thanked Director (Operations), PGCIL for the nice arrangements. He

noted that in the SRPC Meeting, various coordination issues of Southern Region were

being deliberated and the way forward to resolve these challenges was being evolved.

The concerns of all constituents on various issues could be further deliberated in this

Meeting and consensus could be arrived at. He stated that the contribution of Shri K.

Gnanadesikan, erstwhile Chairman, TNEB required special mention for providing

inspiration and guidance during his association with SRPC forum.

1.5 SRPC welcomed the following new Members:

Shri M. Maheshwar Rao, MD, KPCL

Dr M. Saikumar, Chairman, TANTRANSCO

Shri D. Prabhakar Rao, CMD TSTRANSCO & TSGENCO


1.6 SRPC also placed on record the excellent services rendered by the following outgoing

Members:

Shri K. Gnanadesikan, Chairman, TANTRANSCO

Shri S. A. M Rizvi, CMD, TSTRANSCO

Shri Ritesh Kumar Singh, MD, KPCL

Shri K. Vikraman Nair, Director (Tr & SO), KSEB

2. CONFIRMATION OF THE MINUTES OF 25th

MEETING OF SRPC

The Minutes of the 25th

Meeting of Southern Regional Power Committee held on 26th

July 2014 held at Chennai were confirmed.

3. UPCOMING TRANSMISSION SYSTEM

3.1 Perspective Transmission Plan for Twenty Years (2014-2034) – Highlights

3.1.1 MoP in association with CEA, CTU and POSOCO had brought out the Perspective

Transmission Plan for 20 Years (2014-34) and following are the highlights:

Load generation balance shows that deficit in Southern Region is about 13,000 to

19,100 MW at the end of 13th

Plan (2021-22) conditions.

Summary of Inter- Regional Transmission Capacity Corridor towards SR is given

below:

Transmission Element Transmission Capacity in MW

Existing

12

th Plan

addition

End of

12th

Plan

13th

Plan

addition

Total

Balimela-Upper Sileru 220kV S/c 130 130 130

Gazuwaka HVDC back-to-back 1000 1000 1000

Talcher-Kolar HVDC bipole 2000 2000 2000

Upgradation of Talcher-Kolar HVDC

Bipole

500 500 500

Angul - Srikakulam 765kV D/c line 4200 4200 4200

Angul - Srikakulam 765kV D/c line (2nd) 4200 4200

EAST-SOUTH 3630 4200 7830 4200 12,030

Chandrapur HVDC back-to-back 1000 1000 1000

Kolhapur-Belgaum 220kV D/c 260 260 260

Ponda – Nagajheri 220kV D/c 260 260 260

Raichur - Sholapur 765kV S/c line (PG) 2100 2100 2100

Raichur - Sholapur 765kV S/c line (Pvt.

Sector)

2100 2100 2100

Narendra - Kolhapur 765kV D/c (ch at

400kV)

2200 2200 2200

Wardha - Nizamabad 765kV D/c line 4200 4200

Raigarh - Pugalur +/- 800kV, 6000 MW

Bi-pole

6000 6000

Warora Pool - Warangal 765kV D/c line 4200 4200

WEST - SOUTH 5720 2200 7920 14400 22,320


ISTS drawal requirement of each State in 2021-22 had been assessed as follows :

State 2013-14 2021-22

Demand

Met

MW

Peak

Demand as per

EPS

Increment

Load

State

Generation

Despatch

Import

requirement

through

ISTS

%ge of

Peak

AP 6318 15933 9615 9697 6236 39%

Karnataka 9223 18403 9180 7763 10640 58%

Kerala 3573 6093 2520 1119 4974 82%

TN 12825 29975 17150 13053 16922 56%

Telangana 6844 17261 10417 3949 13312 77%

State wise annual peak demand for SR constituents is as given below :

State/UT 14th

Plan (as per 18th

EPS) 2026-27

15th

Plan (as per 18th

EPS) 2031-32

Estimate for

2033-34

AP/Telangana 51601 74818 86805

Karnataka 25396 34720 39346

Kerala 8150 10903 12249

TN 43044 59827 68248

Puducherry 787 940 1009

Southern Region 1,18,764 1,65,336 1,88,730

Load generation balance shows the import assessment for Southern Region in different

scenarios as given below :

Generation Scenario 14

th Plan

(2026-27)

15th

Plan

(2031-32)

2033-34

Scenario I

(Normal Generation as per

plan / resource availability)

3356-20607 19631-41539 27002-51249

Scenario II

(Less gas met through imported

coal with respect to Scenario I)

+507-20607 10165-41538 27002-51249

Requirement for Major Transmission Corridors had been assessed as given below :

13th

Plan

(2021-22)

14th

Plan

(2026-27)

15th

Plan

(2031-32)

2033-34

ER/NER-SR 12000 15000 30000 40000

WR-SR 22000 25000 35000 40000

SR-Sri Lanka 500 1000 1000


3.1.2 For coordinated development process aiming at perspective optimization in meeting

growth targets, it was thought appropriate that State Transmission Utilities prepare their

State Electricity Plans appropriately, focusing on specific requirements of the

concerned State. In Petition No SM/011/2014 before Hon’ble CERC, it had been

stipulated that CTU and STUs shall coordinate with each other and other agencies so

that implementation of ISTS and associated downstream/upstream ISTS is carried out

in a matching time frame so that no asset remains stranded or underutilized and the

intended purpose of the scheme was realized.

3.1.3 The following had been noted in the TCC Meeting:

In earlier Meetings, it had been suggested that a ‘Big Picture’ be

deliberated in SRPC forum which would help in assessment of bottlenecks

and ensure timely corrective actions. MoP in association with

CEA/CTU/POSOCO had come up with Perspective Transmission Plan for

coming two decades. The plan was under draft stage and comments had

been sought. The need for coordinated development by CTU and STU had

been highlighted for optimal planning and utilization of transmission

assets. In a recent petition before Hon’ble CERC, the issue regarding

stranded assets due to non-completion of downstream assets was being

heard. Proof of coordination and action taken by the concerned utilities

had been sought. Section 38 (2) and Section 39 (2) of the Electricity Act

clearly demarcate the responsibility of CTU and STU in the process.

CTU had stated that the projected ISTS import requirements for the states

was quite high and varying between 39% and 82%. Regional Demand

which was currently around 38,500 MW was expected to rise by 50,000

MW and reach about 87,500 MW by 2021-22. By 2026 -27, the demand

of SR was expected to rise to 1, 19,000 MW (about current all India

demand). An action plan with concerted efforts was therefore required,

considering the quantum jump in demand and various bottlenecks likely in

development of the transmission system. CTU had suggested constitution

of a Task Force in this regard.

KPTCL had observed that KPTCL was planning 1,000 Km of 400 kV

transmission lines. It was noted that the Tables projected pertained to the

likely LGBR considering requirement as per EPS figures and anticipated

availability as per proposed generation addition etc. The difference

between requirement and local availability indicated the level of

dependence on ISTS in bridging the gap.

TSTRANSCO had stated that state generation dispatch for the year 2021-

22 appeared to be on the lower side. The State Government was having

ambitious plan for generation additions and the drawal from ISTS could

be of the order of about 9,640 MW. It was suggested to TSTRANSCO that

they may convey revised projected figures to CEA at an early date.

SRLDC had observed that state network too was required to be built in a

coordinated manner with ISTS for effective and full utilization.


MS, SRPC had said that the Plan had been prepared with due consultation

and inputs from the state utilities. However, States could immediately

convey their comments to CEA in event of changes. As suggested by

PGCIL, a Task Force could be constituted which would validate data;

finalize action plan to achieve the desired results and sort out any

coordination issue between CTU/STU/Generators.

After deliberation, it had been noted that sustained coordination was

required between CTU and STU to achieve the desired results. It was

therefore agreed to form a Task Force at the level of Chief Engineers to

study and validate the LGBR projections, Inter Regional Import

requirements, ISTS requirements etc. Task Force would also assess the

intra state transmission system requirement (keeping in view the planned

network). CTU agreed to be associated with this Task Force.

3.1.4 In the Meeting MS, SRPC said that critical issues that could arise in the future in

respect of upcoming transmission system had been highlighted in the Agenda. The

ISTS import requirement assessed was quite high and varied between 39 % and 82 %.

SR demand was expected to rise to about 82,000 MW by 2021-22 and 1,19,000 MW

by 2026-27. Sustained coordinated effort at regional level was therefore essential in

view of the projected quantum jump. Issue of stranded assets on account of non-

availability of downstream systems had been raised in a few petitions and Hon’ble

CERC had sought the action plan. In this regard it had been decided that a Task Force

be formed at the level of Chief Engineer. This mechanism would help develop ISTS

and intra state transmission system in a coordinated manner ensuring better utilization.

3.1.5 Chairperson, SRPC stated that transmission bottlenecks should not come in the way of

smooth evacuation. Surplus generation available in different regions had to be made

available to needy consumers. He suggested that the Task Force as proposed be

formed to study the matter.

3.1.6 After deliberation, SRPC agreed to form a Task Force at level of Chief Engineer to

study and validate the LGBR projections, Inter Regional Import requirements, ISTS

requirements etc. Task Force would also assess the intra state transmission

requirements.

3.2 Associated Transmission System in respect to 765 kV Raichur-Sholapur lines

3.2.1 Additional ATC ( as on date) between WR - SR on account of this link was around

350 (1,100-750 ) MW.

3.2.2 TANTRANSCO vide letter dated 29th

November 2014 (Annexure- II) had stated that

status of remaining lines comprising associated transmission system in WR & SR for

765 kV Raichur-Sholapur 2 x S/C line may be deliberated. The probable quantum of


power increase in WR-SR corridor due to commissioning of new lines in WR & SR

had also been proposed to be discussed.

3.2.3 KSEB vide letter dated 8th

December 2014 (Annexure-III) had stated that status of

lines likely to relieve S1-S2 congestion be discussed in the Meeting. Suitable action

plan may be evolved for early commissioning of the same, including time frame.


Updated status of commissioning of the planned (18 Nos.) transmission elements

in WR and SR for proper utilization of 765 kV Raichur-Sholapur line is as follows:

Sl.

No.

Name of

Transmission

Element

Exe.

Agency

Date as

noted in

CEA

Mtg. held

on

09.09.13

Expected

date Remarks Comments

1. Aurangabad-

Pune 400 kV

D/C

Reliance Dec. 2013 Completed

2. Parli-Pune 400

kV D/C

Reliance Dec. 2013 Completed

3. Raipur-Wardha

765kV D/C

PGCIL May 2014 Nov. 2014 Commissioned

on 15.11.2014

Delayed forest clearance

4. Raipur 765/400

kV S/S

PGCIL Dec. 2013 Completed It is a pooling station.

Interconnecting links

Commissioned

5. Wardha-

Aurangabad

765kV D/C

PGCIL July 2014 Commissioned

in July 2014

One Circuit

Commissioned on 01-07-

2014 against severe

RoW constraints

6. Aurangabad

765/400 kV S/S

PGCIL July 2014 Completed in

July 2014

Interconnecting

network in progress:

400 kV Aurangabad-

Padghe (expected in

June 2015), 400kV

Aurangabad-Boisar

(expected in March

2015), 400 kV Padghe -

Padghe (Kudus)

(expected by June 2015),

MSETCL to take up

commissioning of

Padghe (Kudus) S/S by

June 2015


7. Sholapur-Pune

765 kV S/C

PGCIL Oct.2014 Jan-2015 Pune s/s

critical. Line

being planned

for

commissioning

earlier

bypassing Pune

through

contingency.

Severe RoW

problem.

Sever RoW Problem.

Line is being charged

through Parli by

bypassing Pune S/S

which is expected by

March 2015

8. Pune 765/400 kV

S/S

PGCIL Oct. 2014 March 2015 Civil work

under progress

Land acquisitioned

delayed, Expected

commissioning by March

2015, Civil works and

erection activity in

progress

9. Gooty-

Madhugiri 400

kV D/C

PGCIL June 2014 March 2015 Critical RoW

problems faced

towards

Karnataka end

Hold continues at 10

locations in District

Tumkur. Stringing has

been stopped since Feb

2014

10. Madhugiri

400/220 kV S/S

PGCIL June 2014 March 2015 Erection under

progress

Downstream network not

available

11. Madhugiri-

Yelahanka 400

kV D/C line

PGCIL June

2014 March 2015 Severe Row

Problem

Severe RoW problem at

Tumkur (30 Loc),

Bangalore Rural (35 Loc)

and Bangalore Urban (10

Loc)

12. Raichur-

Kurnool 765

kV S/C

PGCIL Aug-

2014 Commissioned

on 21.06. 2014

13. Kurnool

765/400 kV

S/S

PGCIL Aug-

2014 Commissioned Downstream network

ready

14. Kurnool-

Thiruvalam

765 kV D/C

PGCIL Nov.201

4 Commissioned

on 27.11.2014

Downstream network

ready

15. Thiruvalam

765/400 kV

S/S

PGCIL Nov

2014 765 kV by

Feb 2015

400kV

Commissioned 765 kV by Feb 2015

16. Vijayawada-

Nellore 400 kV

D/C

PGCIL Nov.

2014 March.

2015

RoW problem

being faced at

Krishna Dist.

(49 Loc) &

Guttur Dist (23

Loc)

RoW continuing , efforts

being made including the

Power Secretries meet in

SR Chaired by Union

Power Secretary


17. Nellore-

Thiruvalam

400 kV D/C

PGCIL Nov.201

4 Commissioned

on 14.04.2014

18. Thiruvalam-

Melakottaiyur

400 kV D/C

PGCIL Nov.201

4 July 2014 Commissioned

on 24.07.2014

PGCIL had expressed concern that though 400 kV Gooty - Madhugiri D/C line

would come up , the downstream system at Madhugiri as well as Yelahanka may

not be ready by that time. Stringing on 11-12 towers was pending on Gooty-

Madhugiri lines on account of local compensation issue. Once compensation

issues are finalized by Karnataka Govt. the pending works could be completed.

SRLDC had stated that the utilities were anticipating increase in ATC with

commissioning of new elements. However, in the event downstream system at

Madhugiri and Yelahanka did not come up in the matching time frame, it would

not be possible to enhance the ATC.

KPTCL had informed that Compensation issues were under consideration of the

Govt. of Karnataka and would be settled within 3 months. Complete downstream

evacuation from Madhugiri and Yelahanka had been planned. 220 kV D/C

evacuation lines had been planned from Madhugiri . Initially at Madhugiri, about

500 MVA of evacuation would be possible by July 2015. With regard to

Yelahanka, KPTCL Board had decided that complete evacuation would be

through UG Cable ( 6 kms) since O/H lines were not feasible. 1,500 MVA of

evacuation was planned from Yelahanka and KPTCL was going for adequate

capacity cables despite the high cost involved. It could take 6 to 8 months for the

evacuation system at Yelahanka to come up. Madhugiri and Yelahanka

downstream system would come up in stages from June/July 2015.This factor

would need to be considered while declaring ATC/TTC for different corridors.

CTU had informed that the NEW Grid to SR ATC could be increased by 900

MW with commissioning of 765 kV Sholapur – Pune S/C line, 400 kV Gooty-

Madhugiri-Yelahanka D/C line and downstream system at Madhugiri and

Yelahanka by March 2015. It was clarified that presently Madhugiri substation

would be charged at 400 kV level. With generation addition etc subsequently,

charging at 765 kV level could be planned. Contingency arrangement of

bypassing Pune S/S would be in place by March 2015. ATC from S1-S2 would

be enhanced in stages with commissioning of 765 kV Salem – Madhugiri line,

400 kV Mettur- Thiruvalam D/C lines, 400 kV Mysore – Kozhikode D/C lines

and 400 kV Somanahalli – New Salem D/C lines . ATC would also depend on

the commissioning of KKNPP (2,000 MW), NTPL (1,000 MW), NLC TS-II

Expn (500 MW), BHAVINI (500 MW) and NTECL Vallur 3rd

Unit (500 MW)

etc. Earlier during May 2014 TN, Kerala, CTU & CEA were associated in

studying ATC/TTC computations. A participative approach with mutually

acceptable collective assumptions was required to be adopted to finalize

TTC/ATC computation, especially since spatial distribution of loads etc was

involved.

TANTRANSCO had informed that 400 kV Thiruvalam - Mettur D/C line was

stuck up at 7 locations (out of 799 locations) and they were planning to

commission the same by January 2015, five months ahead of schedule. The failed


transformer at Thiruvalam had been replaced by a new transformer and the same

would be commissioned within 10 days.

MS, SRPC had stressed on the need for participative approach in finalization of

ATC/TTC. The same needed to be backed up with technical rationale and

assumptions on a collective basis. Some issues had been raised regarding

ATC/TTC of CTU and of POSOCO. However, it could be kindly appreciated

that the horizons and assumptions in this regard were different.

KSEB had suggested that the studies be periodically undertaken with

participation from the utilities.

It was agreed that the Study Group would also look into various ATC related

issues with commissioning of lines and Generation. CTU agreed to associate with

the Study Group.

3.2.5 In the Meeting, CTU informed that additionally around 900 MW of power could be

transmitted from NEW grid to SR with the commissioning of new elements by March

2015. ED, SRLDC pointed out that additionally Thiruvalam-Mettur and Somanahalli –

Salem lines as well as downstream system at Madhugiri & Yelahanka S/S was needed

to be in place for enhancement in ATC.

3.2.6 MS, SRPC said that it had been agreed that a Study Committee would look into

ATC/TTC related aspects. A number of issues had been raised on TTC/ATC

computations of CTU & NLDC. However, it could be kindly appreciated that the

horizons, assumptions etc were different for both the studies.

3.2.7 COO, CTU informed that certain MTOA Applications had been received in regard to

which action was required to be completed by 10th

January 2015. Preliminary studies

had been carried out in this regard. She suggested that a Meeting of SR constituents be

held shortly to arrive on a consensus for the ATC between S1-S2.

3.2.8 After deliberations, it was agreed that a Meeting would be conducted on 29th

December

2014 at Bengaluru to look into the ATC issues. MS, SRPC requested CTU to kindly

furnish the study results in advance to the constituents so that the participants could

come prepared for the Meeting. CTU agreed to furnish the details of load flow studies

to the constituents in advance.

3.2.9 ED, SRTS-I informed that during the last one and half years, PGCIL had completed

more than 10 major elements in SR. In respect of Gooty -Madhugiri line, 10

foundations and around 75 Km of stringing was left which could have been completed

as committed. There was demand for stringing corridor to be paid, which was not in

accordance with provisions of the Indian Telegraph Act 1885. Compensation issue had

been taken up with Government of Karnataka at the highest level. Local State


Administration at Madhugiri had informed that unless corridor issue was settled,

stringing could not be carried out. On 7th

July 2014, the local Administration had issued

an Order covering the stringing corridor payment which was around Rs.16 Crores.

Petition had been filed with Hon’ble CERC in this regard and order was awaited. Gooty

-Madhugiri line was transiting 15 Kms in Karnataka and another 15 Kms is Andhra

Pradesh before reentering Karnataka. Farmers in AP were demanding higher

compensation not only for Gooty - Madhugiri line but also for lines coming in other

parts of Andhra Pradesh (Vijayawada – Nellore, Vijayawada area etc.). Once directions

were received on the pending Petitions, works would be taken up.

3.2.10 MS, SRPC said that KPTCL had informed that from Madhugiri S/S, around 500 MW

of evacuation would be possible by July 2015 while evacuation from Yelahanka

substation would be through underground cable. He added that the downstream

system needed to be in place for proper utilization of ISTS.

3.2.11 Director (Tr.), KPTCL informed that tender for Madhugiri evacuation system had been

floated, opened and was in the finalization stage. Regarding evacuation at Yelahanka,

after commissioning of cable (tender to be floated) the 220 kV substation would be

back charged upto 400/220 kV Yelahanka substation of PGCIL. In case 400 kV S/S

and upstream was charged by PGCIL by that time, power could be drawn.

3.2.12 MD, TANTRANSCO informed that Mettur-Thiruvalam line would be commissioned

by January 2015.

3.3 Status of upcoming Inter-Regional links

3.3.1 Narendra-Kolhapur 765 kV D/C line

Transmission

Element

Implement

-ing

Agency

Line

length

(ckm)/

MVA

Capacity

Sch. COD Ant

COD/

Act

COD

Constraints/ Remarks

Kolhapur-

Narendra (New)

765 kV D/C line

(initially charged at

400 kV)

PGCIL 376 April’15 Dec’15

Completion matching

with Kudgi S/S (Land

acquired in Feb’14).

Efforts being made to

complete in 2014-15.

LILO of both circuits

of Kolhapur –

Mapusa 400 kV D/C

line at Kolhapur


Completion matching

with S/S. Efforts being

made to complete in

2014-15.

Narendra (New) –

Narendra (Existing)

400 kV (quad) D/C

line


Completion matching

with S/S. Efforts being

made to complete in

2014-15.


Kolhapur 765/ 400

kV S/S (GIS)


400 kV)

PGCIL April’15 Dec’15

Award placed in

Feb’14. Engg. & Civil

works under progress.

Narendra (New) 765/

400 kV S/S (GIS)


400 kV)


Award placed in

Mar’14. Land acquired

in Feb’14. Civil works

under progress.

Extn. at Narendra

(Existing) 400/ 220

kV S/S


Award placed in

Mar’14. Engg. in

progress.

Kudgi TPS –

Narendra (new) 400

kV 2xD/C Line

M/s Kudgi

Transmissi

on

Limited

(L&T

Infrastruct

ure

Developm

ent

Projects

Ltd.)

Feb’15 Dec’15

Completion matching

with Narendra-

Kolhapur line.

Narendra (new) -

Madhugiri 765 kV

D/C Line

Dec’15 Sept’16

Madhugiri - Bidadi

400 kV D/C (quad)

Line

Dec’15 Sept’16

3.3.1.1 The following had been noted in the TCC Meeting:

SRLDC had pointed out that Kudgi generation would get stranded in case 400

kV Kudgi-Narendra (New), Narendra (New) – Madhugiri and Madhugiri -

Bidadi lines get delayed. There could be issues relating to drawal of Startup

Power as well.

NTPC and KPTCL had clarified that startup power was being arranged

through 220 kV system of KPTCL and the system was in advanced stage of

commissioning.

3.3.1.2 The Committee noted the above.

3.3.2 Wardha - Nizamabad 765 kV D/C line

Transmission

Element Implement-ing Agency

Line

length

(ckm)/

MVA

Capacity

Sch.

COD

Ant

COD/

Act

COD


Wardha-Nizamabad

765 kV D/C line PGCIL 250

Wardha – Raipur PS

765 kV D/C line PGCIL 713 Dec’15

Commissioned on 15-11-

2014

Extn. of Raipur 765

kV S/S PGCIL Dec’15 Completed


Extn. of Wardha 765

kV S/S PGCIL Dec’15 June’15

Engg. & Civil Works

under progress

Wardha –

Aurangabad 765 kV

D/C line

PGCIL 701 Dec’15 July’14

Extn. of Aurangabad

765 kV S/S PGCIL Dec’15 Feb’15 Completed

Extn. of Wardha 765

kV S/S PGCIL Dec’15 Feb’15

Award placed in June’13.

Engg., supply, civil works

& erection are under

progress

Nizamabad-

Maheshwaram PG

(Hyderabad) 765 kV

D/C line

PGCIL 250

Nizamabad-

Dichipalli 400 kV

D/C line

PGCIL

Nizamabad-

Yeddumailaram

(Shankarapalli) 400

kV D/C line

This line along with

“Maheshwaram PG -

Mahboobnagar 400 kV

D/C line” was

recommended for

implementation through

tariff based competitive

bidding (TBCB) route.

Project was recommended

to GoI for notification

Maheshwaram PG

765/400 kV, 2x1500

MVA S/S

PGCIL

Nizamabad 765/400

kV, 2x1500 MVA

S/S

PGCIL

3.3.2.1 In the TCC Meeting, CTU had informed that regarding 765 kV Wardha- Nizamabad

D/C lines, tenders had been floated.

3.3.2.2 In the Meeting, POWERGRID informed that the line from Wardha to Dichipally was

under the scope of PGCIL while Nizamabad – Sankarapalli under TBCB route.

TSTRANSCO requested that the Nizamabad – Sankarapalli line be executed by

POWERGRID in view of its criticality.


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

(TN/KER)]

Transmission Element Imple-

menting

Agency

Line

length

(ckm)/

MVA

Capacity

COD


Sch. Ant /

Act

WR-SR HVDC Bipole Link

[Raighar (Chhatisgarh) - Pugalur

(Tamil Nadu)]

PGCIL

The scheme was

originally designed for

import of 4000 MW and

put up before SCPSPSR-

36 for approval. However,

to cater to the huge import

requirement of power, the

Committee suggested that

studies for 6000 MW

capacity and additional

strengthening be carried

out and put up for

discussion in the next

Standing Committee (37th)

meeting.

Accordingly the scheme

has been modified and

discussed in SCPSPSR-

37, when KSEB requested

to construct this link as a

multi-terminal HVDC

with one Inverter station

of 4000 MW at Pugalur

and another Inverter

station of 2000 MW

capacity at Madakathara

in Kerala by extending the

same HVDC up to

Madakathara to enable it

to import power from

outside.

It was decided that the

same would be explored

and finalized in the next

meeting of SCPSPSR.

Raigarh (existing) - Raigarh (HVDC

Stn) –400 kV 2xD/C (quad) lines

6000 MW, HVDC Terminal Station

at Raigarh 6000

6000 MW, HVDC terminal Station

at Pugalur (or alternatively (i) with

4000 MW HVDC terminal, and (ii)

2000 MW HVDC terminal at

Madakathara, and inter-connection

with existing 400 kV AC Substation

at Madakathara.

6000

Raigarh (HVDC Stn) -

Pugalur(HVDC Stn) 6000 MW, +/-

800 kV HVDC bipole.

Pugalur HVDC station-Pugalur

existing S/S 400 kV D/C(Q) Line

Pugalur HVDC station-Arasur S/S

400 kV D/C (Q) line with 80 MVAR

switchable line reactor at Arasur end.

Pugalur HVDC station-Thiruvalam

S/S 400 kV D/C (Q) line with 80

MVAR switchable line reactor at

both ends

Pugalur HVDC station-

Edayarpalayam S/S400 kV D/C (Q)

line with 63 MVAR switchable line

reactor at Edayarpalayam end

Edayarpalayam S/S-Udumalpet

S/S400 kV D/C (Q) Line

400/230 kV, 2x500 MVA,

Edayarpalayam S/S with 2x125

MVAR bus reactors. 2x500


The matter regarding proposed HVDC link between Raigarh - Pugalur had been discussed

in the 25th

Meeting of SRPC. After discussions it had been felt prudent to recommend to

Ministry of Power that this proposed link be developed by Power Grid Corporation at the

earliest. Only Power Grid Corporation had the desired technical and financial expertise to

take up the project in a timely manner. Accordingly, Chairperson, SRPC vide letter dated

25th

September 2014 (Annexure-IV) had taken up the matter with Secretary (Power),

Government of India.


PGCIL had appraised the forum about the different configurations and

technology options for Multi-Terminal HVDC Link. Decision on the

configuration and technology option was critical. In one option, the voltage

level from Pugalur to Madakathara could be brought down thereby

considerably reducing the RoW requirement. Use of cable partially in

Kerala portion could also be contemplated. On a query it was informed that

this would be the third link of +/- 800 kV, the first being from North East to

Agra and the second one from Champa to Kurukshetra.

KPTCL had suggested that usage of Covered Conductor could be explored

which would help considerably reduce the RoW requirement on the Pugalur

- Madakathara Section.

It was agreed that PGCIL would circulate different technology

options/configurations for consideration. The matter would be further

deliberated in the Standing Committee on Power System Planning.

3.3.3.2 In the Meeting, Director (O), PGCIL said that HVDC system upto Pugalur (6,000 MW)

would be implemented by PGCIL. He however observed that construction of

transmission lines within Kerala was rather difficult. PGCIL had been stuck up with one

line in Kerala for the past 7 years or so. He suggested that Kerala may take care of

evacuation within the state. Kerala could also consider transmission through cable for

which the technology would be different. PGCIL would place the Order for the HVDC

station (at Trichur) but execution would be after completion of line by Kerala. PGCIL

would not like to jeopardize the HVDC link because of transmission constraints in

Kerala.

3.3.3.3 Chief Engineer (Tr.), KSEB informed that they were exploring all possibilities and

within one or two weeks, the option may get finalized. Reducing voltage from 800 kV

to 266 kV and bringing in a new line at 266 kV level was one option. All possible

options would be considered and in case required KSEB may also take up construction

of the line. He requested full support from PGCIL in the design and engineering

aspects.


3.3.3.4 Director (O), PGCIL said any option proposed by KSEB would need to be put up to

Standing Committee for further deliberations. He added that N-1 contingency had

already been factored in and 6,000 MW of power would be available even after outage

of one block.

3.3.3.5 Director (Tr.), KPTCL suggested that on account of severe RoW issues in Kerala, the

proposed terminal at Trichur could instead be located at Mysore. The power deficit

northern part of Kerala could then be fed from Mysore. He stated that system studies

could help decide the location of the terminal.

3.3.3.6 Chief Engineer (Tr.), KSEB observed that the terminal location at Trichur had already

been frozen and should not be reopened.

3.3.3.7 MD, TANTRANSCO stated that 4,000 MW of power evacuation at Pugalur end was

needed to be ensured, irrespective of location of the other landing point.

3.3.3.8 CTU pointed that the scheme (landing point etc) had already been deliberated and

agreed in the 37th

Standing Committee on Power System Planning.

3.3.3.9 The Committee observed that the scheme / technology option etc. would be finalized by

the Standing Committee.

3.3.4 Angul - Srikakulam PS 765 kV D/C line

Transmission

Element

Implementing

Agency

Line

length

(ckm)/

MVA

Capacity

COD

Constraints / Remarks

Sch.

Ant /

Act

Angul - Srikakulam

PS 765 kV D/C line

PGCIL

552

Jun'15 Jun'15

Processing of forest

case very slow at state

govt. level; Critical.

Extn. 765/400 kV

Angul Sub station PGCIL

1x1500

Jun'15 Jun'15

Engineering, Civil works

under progress.

765 kV D/C Angul-

Jharsuguda line PGCIL

570

Dec'15 Dec'15

RoW being faced

765 kV D/C

Jharshuguda-

Dharamjayagarh line

PGCIL 230 Dec'15 Dec’15

Award placed in

May’14. Foundation

commenced from

Sept’14.

Extn. of 765/ 400 kV

Angul SS PGCIL

Dec'15 Dec’15

Award placed in Aug,13.

Engineering & Civil

works under progress



Jharshuguda SS PGCIL

Dec'15 Dec’15


Engineering & Civil



Dharamjaigarh SS PGCIL

Dec'15 Dec’15


Engineering & Civil


Srikakulam P P-

Vemagiri- II Pooling

station 765 kV D/C

line

M/s Vizag

Transmission

Limited

(A subsidiary

of PGCIL)

30.08.2

016 July’16 Under implementation

Srikakulam Pooling

Station 765/ 400 kV,

2x1500 MVA PS (400

kV - AIS & 765 kV –

GIS)

PGCIL 2x1500 Jun'15 Jun'15 Engineering, Civil works

& supply under progress.

Srikakulam Pooling

Station – Garividi 400

kV (Quad) D/C line

with 80 MVAR

switchable line reactor

at Garividi end.

PGCIL

The line has been

approved as ISTS

scheme for

implementation in

SCPSPSR-37.

400/220 kV S/S at

Maradam (Garividi) APTRANSCO

Tenders will be called

for shortly

Behrampur-

Gazuwaka 400 kV

D/C line

M/s Talcher

Transmission

Company

Limited

(Subsidiary of

M/s Reliance

Power

Transmission

Company

Limited)

290 CERC ROP (for

18.11.2014) enclosed

CEA letter 17.11.2014 :

No physical progress

visible on ground.

The scheme needed to be

implemented without any

further delay

Talcher II –

Behrampur 400 kV

D/C line

220

Talcher II- Rourkela

400 kV D/C Quad

line

161

Behrampur 400/220

kV, 2x315 MVA S/S 2x315


APTRANSCO had stated that 400 kV Srikakulam – Garividi D/C line needs

to be expedited.

CTU had informed that this line is under TBCB route and APTRANSCO

could recommend it to be executed by PGCIL, if so desired.

Regarding Talcher-II back up scheme, it was noted that a Petition in this

regard was being heard by Hon’ble CERC.

3.3.4.2 In the Meeting, TSTRANSCO stated that possibility of drawing power by Telangana

through Angul- Srikakulam line needed to be examined. CTU clarified that an inter-

regional line would generally help increase the ATC, irrespective of its actual


connectivity in this region. Increase in Drawal capability of any utility may however

depend on the quantity of additional access granted to it.

3.3.4.3 CTU informed that evacuation schemes had been discussed and finalized in a

comprehensive manner in the 37th

Meeting of Standing Committee. Hyderabad was

getting well connected to Wardha and Warora, while evacuation beyond Vemagiri to

Chilkalurupeta/Cuddapah was through the TBCB route.

3.3.4.4 APTRANSCO suggested that CTU may take up execution of 400 KV Srikakulam –

Garividi line. They informed that they would take up the matter with Empowered

Committee regarding execution by CTU of this line keeping in view the urgency.

3.3.5 Warora Pool – Warangal 765 kV D/C line

Transmission

Element

Implementing

Agency

Line

length

(ckm)/

MVA

Capacity

COD

Constraints / Remarks

Sch.

Ant /

Act

Warora Pool –

Warangal 765 kV

D/C line

This line has been

approved as additional

inter-regional link for

importing power into

Southern Region, and

recommended for

implementation in

Southern Region’s

Standing Committee on

Power System Planning in

its 37th

meeting held on

31.07.2014

Warangal (New) –

Hyderabad 765 kV

D/C line

Warangal (New) –

Warangal (existing)

400 kV (quad) D/C

line.

Warangal (New) –

Chilakaluripeta 765

kV D/C line

Warora 765/400 kV,

2x1500 MVA S/S PGCIL 2x1500

Warangal (New)

765/400 kV, 2x1500

MVA S/S

PGCIL 2x1500


3.3.5.1 In the TCC Meeting, CTU had informed that the scheme was discussed in the

Empowered Committee and is coming through TBCB route.

3.3.5.2 In the Meeting, CMD, TSTRANSCO requested that Warora – Warangal Line be

kindly expedited. ED, SRTS-I, PGCIL clarified that the lines were to be executed

under TBCB route. It was also noted that matter regarding Vemagiri – Khammam –

Hyderabad line was before Hon’ble CERC.

3.4 Status of upcoming links having impact on S1-S2

3.4.1 Following is the updated status of the links having impact on S1-S2 ATC:

Sl.

No. Transmission Element Schedule Remarks

1 400/230 kV Thiruvalam S/S and

associated LILOs

Both the ICTs and LILOs

completed by October 2014.

2 400 kV Thiruvalam - Melakottaiyur Commissioned on

24.07.2014

3 400 kV Somanahalli- New Salem June. 2015

Approval for enhanced

compensation is awaited from

CC,PGCIL

4 400 kV Pugalur- Kalavindapattu Both ckts commissioned

5 765 kV Kurnool-Thiruvalam Commissioned on

27.11.2014

6 400 kV Mettur- Singarapet- Thiruvalam Jan. 2015

7 LILO of Kolar- Sriperumbudur at

Thiruvalam Commissioned in March

2014

8 400 kV Mysore-Kozhikode May. 2015 Held up due to ROW issue.

9 400 kV Mangalore (UPCL ) -Kasargode-

Kozhikode

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.


3.4.2 It had been noted that CTU had not been specifying the ATC of S1 – S2 corridor.

CTU/POSOCO were to appraise the forum of the schedule of release of ATC.

TANTRANSCO vide letter dated 29th

November 2014 (refer Annexure-II) had stated

that the present status of erection work of lines to relieve S1-S2 corridor congestion

may please be discussed. In addition, Karnataka had to cater their Yerandahalli load of

80 MW from Somanahalli itself. It had also been stated that though SPS on 400 kV

Hosur-Salem D/C line had been provided by Tamil Nadu, the ATC had not been

increased. Further, due to drawal of KSEB, the flow on 400 kV Kolar-Hosur D/C line

was always maintained high.


KPTCL had stated that with regard to proposed UPCL-Kozhikode line,

they had furnished their comments, keeping in view the planned 2,000 MW

HVDC terminal at Madakathara. It had been opined that the scheme needed

to be justified technically before looking into any commercial issue.

SRLDC had stated that the UPCL-Kozhikode line was necessary from the

reliability point of view. Under PoC regime, transmission charges would be

borne by the concerned utility using the system. CTU stated that the

scheme had been planned keeping in view comprehensive perspective LGB

scenario. PGCIL also observed that presently there was no N-1 reliability

for the UPCL plant. This link would thus improve reliability under N-1

contingency. They also informed that a site survey had been carried out

recently with the participation of CEA. MS, SRPC noted that the scheme

had been agreed in the Standing Committee and also by SRPC.

KSEB had observed that all concerned issues had been studied and

subsequently only the scheme had been approved. The line was absolutely

necessary for connectivity to North Kerala. Two more units were also

likely to come up in the UPCL complex; hence the requirement of the line

is more justified.

Regarding Thiruvalam- Mettur line, MD, TANTRANSCO informed that

the line was held up at 14 towers due to NGT clearances. They were

hopeful of getting the line through by January 2015.

3.4.4 In the Meeting, ED, SRTS- II, PGCIL informed that order regarding enhanced

compensation in respect of 400 kV Somanahalli- New Salem line was awaited.

PGCIL Management would take a suitable decision in this regard.

3.4.5 MD, TANTRANSCO stated that shut down of 45 days in respect of Somanahalli –

Salem line could be allowed during wind season in TN (after April / May 2015).

3.4.6 Director (Tr.), KPTCL informed that in view of the changed scenario ( HVDC at

Trichur), a letter had been addressed in respect of UPCL- Kasargode – Kozhikode

line.


3.4.7 ED, SRLDC said that from the reliability point of view UPCL- Kasargode –

Kozhikode line was highly essential.

3.4.8 Chief Engineer (Tr.), KSEB said that the proposed link (UPCL- Kasargode –

Kozhikode) would help KPTCL also in smooth evacuation of power from UPCL,

even under outage of UPCL- Hassan line. He added that joint inspection with

participation of CEA had already been carried out. Additional units were also being

planned in UPCL. Space for 400 kV substation at Mylatti had been identified. No

RoW constraints were anticipated in the Kerala portion of the line. The scheme had

already been approved in Standing Committee. He stated that KSEB was not aware of

KPTCL letter in this regard and requested for a copy of the same.

3.4.9 RoW of 400 kV Mysore-Kozhikode D/C line

3.4.9.1 In the 25th

Meeting of SRPC the following had been noted:

KSEB had stated that the completion of 400 kV Mysore-Kozhikode

(Areakode) D/C line is urgently required since Northern Kerala was facing

acute power shortage. Due to forest clearance and RoW disputes, the line

work was held up in Karnataka. 400 kV line works in Kerala and

construction of 400 kV substation at Areakode had been completed and kept

idle for want of this line.

KPTCL had informed that Karnataka State Government had constituted an

Expert Committee to examine alternative possibilities for this line. The

Committee had almost finalized the Report which was expected to be

submitted shortly.

3.4.9.2 In the 101st OCC Meeting on 11

th November 2014, SR-II, PGCIL had informed that

the works on this line had resumed. The status may please be appraised by

POWERGRID. Petition No. 120/MP/2014 was heard by Hon’ble CERC on 13th

November 2014. The Commission had reserved order in the petition.


PGCIL had informed that they had resumed work with support of State

Govt. In case conducive environment persisted, they would complete this

line by June 2015.

KSEB had stated that the line was extremely critical for North Kerala.

They suggested that PGCIL may deploy multiple agencies to expedite the

works.

KPTCL had assured that they would continue to support PGCIL for

completion of works on this line.

3.4.9.4 In the Meeting, CE (Tr. & SO), KSEB reiterated that Mysore – Kozhikode line was

needed to be commissioned at the earliest, since northern part of Kerala was facing

acute constraint.


3.5 Other upcoming Intra-regional transmission elements

3.5.1 Updated status of other critical upcoming lines is given below:

Sl.

No. Transmission Element Schedule Remarks

1 765 kV Salem- Madhugiri December

2015

Severe RoW problem near

Madhugiri.

2 400kV Krishnapattanam- Chittoor March 2015 APTRANSCO was requested to

expedite commissioning to

avoid evacuation constraints.

SRLDC had stated evacuation

should be restricted to 800 MW.

3 400kV Almathy-Thiruvalam D/C line Jan.2015 ROW issues at 17 locations.

4 400 kV Edamon-Kochi Held up due to RoW issue.

KSEB informed that GO for

compensation is awaited. KSEB

was requested to settle the

compensation issues within one

month to enable PGCIL to

initiate works.

3.5.1.1 In the TCC Meeting, regarding Krishnapattanam - Chittoor, APTRANSCO had

informed that they would commission the planned evacuation system by March

2015. SRLDC had stated that during the interim period, evacuation had to be

restricted to 800 MW from Krishnapattanam JV.

3.5.1.2 The Committee noted the above.

3.5.2 400 kV Edamon-Kochi line

3.5.2.1 In the 25th

Meeting of SRPC, the following had been noted:

POWERGRID had filed a petition before Hon’ble CERC seeking

provisional tariff on the expenditure incurred on construction of Edamon -

Cochin 400 kV D/C (Quad) line till 31.03.2014 and adjudication of dispute

between the petitioner and Govt. of Kerala with regard to the compensation

determined by the latter in terms of Section 67 (4) of the Electricity Act.

Hon’ble CERC had issued RoP in respect of Petition No. MP/083/2014

(date of hearing 17th

June 2014) wherein the following was stated:

“(d) Under the circumstances, the petitioner finds no way to complete the

Projects and seeks recovery of expenditure already incurred in a suitable

manner. “

KSEB had informed that it had been decided that additional compensation

of about Rs. 341 Crores would be borne by the Government of Kerala. They

were in discussion with PGCIL to work out the schedule and works were

likely to commence by mid-August 2014.


3.5.2.2 In the 101st OCCM, KSEB had informed that they are extending all support for the

early completion of Tirunelveli- Kochi line in Edamon – Kochi portion. KSEB had

already taken up the task of liaisoning and a senior Executive Engineer has been

assigned the dedicated task.

3.5.2.3 Petition No. MP/083/2014 was heard by Hon’ble CERC on 13th

November 2014. The

Commission had reserved order in the Petition.


PGCIL had expressed concern that despite several Meetings, assurance on

compensation issues being settled by Kerala Govt etc. there had virtually

been no progress at ground level. Around one and half year ago, PGCIL

had stated that they were ready to abandon this line and that KSEB could

take over and execute the pending works.

KSEB had informed that the G.O. of Kerala Govt. on enhanced

compensation was awaited and the same was expected within a month.

KSEB assured that RoW issues would be settled enabling PGCIL to take

up the works.

KSEB was again requested to settle the compensation issues within one

month in the interest of speedy completion of pending works.

3.5.2.5 In the Meeting, ED, SRTS-II, PGCIL informed that it was becoming extremely

difficult for PGCIL to continue with the project. They were willing to wind up the

project or else Kerala could take over the line.

3.5.2.6 On a query from Chairperson, SRPC on compensation, CE, KSEB informed that

compensation at higher rate amounting to Rs.321 Crores would be paid by

Government of Kerala for tower foot print as well as corridor also. Steps had been

initiated and once GO is issued, compensation issue would get settled.

3.5.3 400 kV Trichur-Kozhikode line (Madakkathara- Areakode)

The following had been noted till 25th

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.


3.6 Transmission Constraints Requiring Attention

Following constraints had been noted in various fora:

Overloading of Hiriyur- Nelamangala D/C & Jindal‐BTPS S/C Line

Till parallel lines are developed KPTCL to restrict upstream

generation and downstream load.

Prioritizing and expediting commissioning of the transmission system

planned for Yermarus TPS .

Early Commissioning of 220 kV Hiriyur ‐ Gowribidanur D/C line

under construction by KPTCL would help in relieving this line to

some extent.

In the TCC Meeting the KPTCL had informed the following:

Out of 120 Km of 220 kV Hiriyur – Gowribidanur line, 118 Km had

been completed and test charged from the other end. Out of 436

locations 434 locations foundation have been completed while 429

towers had been completed. The completion was being followed up

and the line is expected in January 2015.

JWSEL is executing 400 kV S/S at Bellary which would be handed

over to KPTCL. Tenders finalized for 400 kV Bellary – Madhugiri

line (200 Km). Schedule for completion is 24 months with incentive

clauses for early commissioning. For 400 kV Bellary – Yeramarus

line, tenders would be shortly floated

400 kV Chikanayakanahally – Bellary (JSWEL) would be taken up

once the land acquisition for Chikanayakanahally S/S is finalized

The Committee noted the above.

Hinduja Evacuation

Till the ATS is developed total injection at Vemagiri to be restricted

to 600 MW.

In the TCC Meeting, APTRANSCO had informed that the

evacuation scheme was expected in about 8 Months. They assured

that injection from the Vemagiri complex would be restricted to

600 MW till evacuation system is in place.


Overloading of 230 kV and below system in TN during high wind

season also leading to low voltages

Identified evacuation lines to be developed by TANTRANSCO to be

prioritized and expedited.

Provision of Under Voltage Relays (UVR) to be ensured.


The following had been noted in the TCC Meeting:

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.

The Committee noted the above

Once S1-S2 lines are in place the loading on 400 kV Salem‐Udumalpet

would be a concern

400 kV Mettur‐ Thiruvalam line to be expedited

In the TCC Meeting, TANTRANSCO had informed that Mettur-

Thiruvalam line would be commissioned by January 2015.


Overloading of Khammam‐Nagarjuna Sagar S/C line

400 kV D/C line between Khammam and Nagarjuna Sagar to be

expedited.


TSTRANSCO had stated that presently there was no overloading

of Khammam- Nagarjunasagar S/C line.

SRLDC had clarified that this was a future anticipated constraint.

PGCIL had informed that 400 kV Khammam - Nagarjunasagar

line (under TBCB) would come up in the first quarter of 2016.



Overloading of 400/220kV 500 MVA ICTs at Somanahalli 2 Nos.&

Radialization of Lines

Redistribution/ reconfiguration of 220 kV transmission lines around

these substations is required.


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 400/220kV 315MVA ICTs at Mysore‐ 2Nos.

Strengthening at 220 kV level around Mysore is required. This needs

to be planned by KPTCL. 500 MVA ICT expected by 2017 (award

placed in September 2014).

In the TCC Meeting, PGCIL was requested to expedite the

commissioning. PGCIL agreed to prioritize and expedite the

commissioning of the ICT.


Overloading of 400/220kV 315MVA ICTs at Kalvindapattu‐2 Nos

Commissioning of newly planned substations at Thiruvalam and

Sholinganallur would help 500 MVA ICT expected by 2017. ( award

placed in September 2014)

In the TCC Meeting, PGCIL was requested to expedite the

commissioning. PGCIL agreed to prioritize and expedite the

commissioning.

In the Meeting SRTS-II, PGCIL informed that order had been placed and they

would try to expedite commissioning to the extent possible.

Overloading of 400/220kV 315MVA ICTs at Trichur‐ 2Nos and

Palakkad‐ 2Nos

Loading of ICTs at Trichur would ease after Mysore-Kozhikode 400

kV line. 3rd

ICT at Trichur (315 MVA) was commissioned on 31st

October 2014.


In the TCC Meeting, it was noted that the situation may get

mitigated after commissioning of 400 kV Mysore-Kozhikode

lines. In the meanwhile KSEB was suggested to take steps to

avoid any overloading of the ICTs at Trichur and Palakkad.


400 kV Udumalpet – Palakkad D/C lines are heavily loaded during

high drawal by KSEB

This could limit the drawal by Kerala in future.


Udumalpet - Palakkad lines were violating N-1 criteria in certain

occasions.

KSEB was requested to take steps to avoid overloading of

Udumalpet - Palakkad D/C line. There should be no overdrawal

during N-1 contingency.


400/220 kV 315 MVA ICTS at Gazuwaka are overloaded


PGCIL had suggested that the 315MVA ICTs be replaced with

500 MVA ICTs on account of space constraints. The 315 MVA

ICTs could be utilized as regional spare.

TCC had recommended for up-gradation of 2x315 MVA ICTs to

2x500 MVA along with associated bay equipment. Two 315

MVA ICTs would be utilized as regional spare.

The Committee approved up-gradation of 2x315 MVA ICTs to 2x500 MVA along

with associated bay equipment. Two 315 MVA ICTs would be utilized as regional

spare.

Loading on 220 kV Kadakola –Kaniampetta lines

In the 101st OCCM (held on 11.11.2014) KPTCL had informed that

there had been loss of elephant life due to electrocution close to this

corridor. Keeping the various issues in mind, the loading was needed

to be restricted to 120 MW on this line.

KSEB categorically stated that any further reduction in the power

flow through this line would result in perpetual load shedding in

Northern Kerala and cannot be agreed upon. Special maintenance for

the line had already been discussed in earlier SRPC Meetings.


It was agreed that loading upto 150 MW would continue and the issue

would be put up to TCC.


KPTCL had informed that they had assessed the requirement for

intermediate towers at critical locations and tenders would be

called shortly. KPTCL would share the corridor details with

KSEB..

Similarly, KSEB had also been suggested to assess and furnish

corridor details in their portion.

KSEB had stated that they would also examine the issues in

coordination with KPTCL. They agreed to furnish the details

within one month time. In the meantime, flow on the line would

be allowed upto 150 MW. It was also pointed out that any

shutdown of this line could only be agreed after commissioning of

400 kV Mysore-Kozhikode line. KSEB agreed to restrict the

loading below 150 MW in all instances.

It was noted that the issue would be deliberated in a Meeting to be

held on 9th

January 2014 at PCKL.

In the Meeting, CE, KSEB informed that there was no clearance issue in Kerala

portion of the line.

KPTCL suggested that OCR at 150 MW could be activated to restrict the flow.

KSEB assured that flow would be restricted to 150 MW and OCR was not

required.

220 kV Sharavathy –Talaguppa lines over loading

In the TCC Meeting, KPTCL had informed that reconfiguration

works would be completed within 3 months


Strengthening of Hyderabad downstream system


TSTRANSCO had informed that a number of lines and

substations had been planned in the Hyderabad area for

augmentation purposes.

SRLDC had requested that these details be shared by

TSTRANSCO. TSTRANSCO agreed to furnish the details.

TSTRANSCO informed that 9 nos 220 KV substations were

planed around Hyderabad.



Rayalaseema TPP – Chinakampally lines overloading

In the TCC Meeting, APTRANSCO had informed that 3rd

D/C

line would be commissioned by end February 2015.


Nellore ICT Overloading

In the TCC Meeting, APTRANSCO had informed that 3rd

ICT

would be commissioned within 3 months’ time.


Additional ICT at Vijayawada


APTRANSCO had requested for expediting the commissioning of

additional ICT at Vijayawada.

PGCIL had informed that the Order for 3rd

ICT at Vijayawada had

been placed and they would expedite the commissioning.


Overloading of Hosur-Shoolagiri


TANTRANSCO had informed that approval has been accorded for

2nd

circuit of Hosur – Shoolagiri. Approval was under progress for

Uddanapalli S/S (near Hosur).

KPTCL had informed that system strengthening was under progress

and they would be able meet the load from their end without

depending on Hosur by July 2015.


PST at Kothagudem

In the TCC Meeting, TSTRANSCO had informed that the Phase

Shifting Transformer (PST) has been synchronized on 1st

December 2014 with objective of relieving the 220 kV network

and injecting more power into 400 kV network.


3.7 Closing of Upper Sileru-Balimela Line

3.7.1 In the 25th

SRPC Meeting it had 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.

3.7.2 SR constituents were ready for trial operation and the line was closed from AP end.

In the 99th

OCC it had been agreed to have a trial operation on 19th

September 2014.


In the 101st OCC Meeting, APTRANSCO had informed that temporary

reconfiguration (Upper Sileru-Pendurthi) carried out due to “Hud Hud” cyclone, the

exercise would not be possible till the original system is restored.

3.7.3 In the TCC Meeting, APTRANSCO had informed that normalization works would

take about 10 days. There were some issues with Railways which had been sorted out.

Subsequently, trial operation could take place on the Upper Sileru – Balimela line.

3.7.4 In the Meeting, MS, SRPC said that the line was needed to be closed at the earliest and

that the matter was also being reviewed by MoP. He noted that 150 MW flow on this

line had been considered as import capability towards SR in the Perspective Plan.

3.7.5 The Committee noted the above.

4. TRANSMISSION LINES APPROVED IN 37th

MEETING OF SCPSPSR

4.1 The 37th

Meeting of Standing Committee on Power System Planning of Southern

Region (SCPSPSR) was held on 31st July 2014. The Minutes of the Meeting along

with Corrigendum is enclosed as Annexure-V.

4.1.1 TCC had recommended the Schemes (along with the Corrigendum) as agreed in the

37th

Meeting of Standing Committee on Power System Planning of Southern Region

(SCPSPSR) held on 31st July 2014 for approval.

4.1.2 The Committee approved the Schemes (along with the Corrigendum) as agreed in the

37th

Meeting of Standing Committee on Power System Planning of Southern Region

(SCPSPSR) held on 31st July 2014.

4.2 Evacuation System for Ultra Mega Solar Park (1,000 MW) in AP


PGCIL had appraised the forum about the urgent evacuation need for 1,000

MW Ultra-Mega Solar Park in Anantapur District of Andhra Pradesh since

gestation period for Solar Park was quite short (PGCIL Agenda at

Annexure-VI). This important prestigious renewable project was being

followed up at the highest level. Under Phase-I, evacuation for 250 MW was

being planned. Tender for S/S had already been issued and the same for

transmission line package was under process. The complete scheme would

be taken up with Standing Committee for ratification. The proposed

transmission scheme is as under:


Phase-I

Establishment of 3 x 500 MVA, 400/220 kV Substation at NP Kunta.

LILO of 400 kV Kadapa-Kolar S/c Line at NP Kunta.

1 x 125 MVAR Bus Reactor at NP Kunta along with +- 100 MVAR

STATCOM.

Phase-II

NP Kunta – Kadapa 400 KV D/C line.

LILO of 765 kV Kurnool – Thiruvalam D/C at Kadapa*

Up gradation of Kadapa S/s at 765 kV with 2 x 1500 MVA, 765/400 kV

transformation capacity*

2 x 240 MVAR Bus Reactors at 765 kV Kadapa S/s*

* Already approved in the 37th

SCPSPSR as System Strengthening

Scheme XXIV in SR being implemented by POWERGRID.

KSEB had enquired whether this scheme would curtail the margin for S-2

constituents in any manner. CTU had clarified that this scheme would only

help in making more power available at the mouth of S-2 region.

TCC had recommended the scheme for approval, subject to necessary

ratification of the Standing Committee on Power System Planning.

4.2.2 The Committee approved the scheme, subject to necessary ratification of the Standing

Committee on Power System Planning.

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

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

5.1.1 In the 24th

& 25th


NTPC had informed that synchronization of Unit-I was expected during

September 2015 and Unit-II during March 2016.

KPTCL had informed that chunk of land for Stage-II had been identified

near Stage-I. NTPC could expedite activities relating to Stage-II also.

NTPC had informed that they were in the process of firming up coal

requirements/availability and subsequently other activities could be taken

up.

NTPC had informed that on 5th

July 2014 there had been a law & order

incident involving disruption. Works had come to a standstill. Though the

State Government was extending full support, the workmen were yet to

come back. The concerned agencies were being asked to get the workmen

back to site. In such a scenario, it would be difficult to estimate the effect of

this disruption on the project schedule.



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 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 25th


NLC had informed that BHEL had committed synchronization of Unit-1 by

mid-August 2014. CoD of Unit-I was expected during August 2014 and

CoD of Unit-II during September 2014.

NLC had again filed a Petition for extension of injection of infirm power

until 31st March 2015. The delay in commissioning was affecting S1-S2

ATC also.

5.2.2 In the 26th

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

2014, NLC had informed that CoD of Units I & II are expected by December 2014.

5.2.3 In the TCC Meeting, 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.


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

5.3.1 The following had been noted in the 25th

Meeting of SRPC:

NLC had informed that CoD of Unit-I & Unit –II was expected by October

2017 & April 2018 respectively.

5.3.2 In the TCC Meeting, NLC had informed that there was no change in the schedule.



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

5.4.1 Following had been noted in the 25th

Meeting of SRPC:

NPCIL had filed Petition before Hon’ble CERC praying that they be

permitted injection of infirm power to the grid till declaration of CoD of

KKNPP Unit-1 or 22.10.2014, whichever is earlier.

NPCIL had informed that final phase of pre CoD tests were continuing.

Unit-I was under shutdown as per AERB requirements and CoD of the unit

was expected by end of August 2014. Synchronization of Unit- II was

planned by December 2014 and CoD by March 2015.

5.4.2 Subsequently, NPCIL had filed Petition (Petition No. 408/MP/2014) seeking permission

of Hon’ble CERC to continue injection of infirm power in Southern Grid till declaration

of COD of Unit-I or 22nd

January 2015, whichever is earlier. Hon’ble CERC vide order

dated 10.11.2014 had allowed extension of time for injection of infirm power into the

grid for commissioning tests including full load test of unit up to 22.1.2015.

5.4.3 MoP vide letter dated 10th

November 2014 (Annexure-VII) had allocated 50 MW

unallocated power of Second Unit (1000 MW) of KKNPP to Telangana. This is to be

implemented from the date of commercial operation of the unit.


NPCIL had informed that 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.

PCKL had observed that the allocation to Telangana needed to be

ascertained since AP & Telangana were not the original beneficiaries of the

project.

MS, SRPC had clarified that allocation of unallocated power was at the

discretion of MoP.


5.5 BHAVINI- Kalpakkam PFBR (500 MW)

5.5.1 In the 24th

/ 25th


TANTRANSCO had informed that tender in respect of Kancheepuram S/S

had been finalized and the substation was expected to be ready by

September 2014.

Reactor could go critical by September 2014 and power injection was

expected by November 2014.

5.5.2 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 NTECL - NTPC & TNEB Joint Venture - Vallur STPS Unit- III (500 MW)


Meeting of SRPC:

NTECL had informed that all activities except CHP had been completed

and they were putting best efforts to complete balance works by August

2014. As abundant precaution, NTECL had approached Hon’ble CERC

seeking permission for infirm power injection up to 15th

October 2014.

5.6.2 Subsequently, Hon’ble CERC vide order dated 25.08.2014 had allowed extension of

time for injection of infirm power into the grid for the commissioning tests including

full load test of Unit-3 up to 15.10.2014 or actual date of commercial operation,

whichever is earlier. Further vide Order dated 17.10.2014, Hon’ble CERC in Petition

No. 392/MP/2014 had allowed extension of time for injection of infirm power into the

grid for the commissioning tests including full load test of Unit up to 31.12.2014 or

actual date of commercial operation, whichever is earlier.

5.6.3 In the 26th


2014, NTECL had informed that CoD of Unit III is expected by December 2014.

5.6.4 In the TCC Meeting, NTECL had informed that most of the issues had been resolved

and CoD was expected before 31st

December 2014.


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

at Tuticorin (2x500 MW)


Meeting of SRPC:

NLC had informed that the unit was in the final phase of commissioning.

CoD of Unit-I expected by August 2014 & CoD of Unit- II expected by

September 2014.

5.7.2 In the 26th


2014, NLC had informed that CoD of Unit - I is expected by December 2014 and Unit-

II by February 2015.

5.7.3 In the TCC Meeting, 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. Unit –II CoD was scheduled by March

2015.



5.8 Krishnapattanam UMPP (6x660 MW)

5.8.1 In the 25th

Meeting of SRPC, APTRANSCO had informed that the matter was before

Hon’ble CERC as well as Hon’ble Delhi High Court. It was understood that Hon’ble

CERC had asked Reliance Power to first settle the matter before High Court and revert

back. The Developer had sought a Meeting with the procurers. TN had requested AP to

kindly continue to take the lead and arrange a Meeting at the earliest. APTRANSCO

had assured that a Meeting would be called at the earliest.

5.8.2 In the TCC Meeting, 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.


5.9 Cheyyur UMPP (4000 MW)

5.9.1 In the 25th

Meeting of SRPC, it had been noted that the project had now been revived.

RfQ had been issued and project developer (M/s Coastal Tamil Nadu Power Ltd. - SPV

of PFC) had applied for LTA to CTU.

5.9.2 In the TCC Meeting, 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.


5.10 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

February 2016

(CoD by April

2016)

Unit-II: CoD by

October 2016

Construction activities in

progress. Evacuation issues

needed to be addressed.

NLC

Neyveli-II Expn. I 250 1st week of January

2015

Injection of infirm power sought

up to March 2015

II 250 End of January

2015

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 by 22nd

January 2015

Synchronized on 22nd

October

2013. Reached 1000 MW

generation level.

II 1000 Synchronization by

July 2015

Work in progress

BHAVINI

Kalpakkam

(PFBR)

I 500 March 2015

NTECL ( NTPC & TNEB JV)

Vallur STPS I 500 Original schedule:

February 2011

CoD on 29.11.2012

II 500 Original schedule:

August 2011

CoD on 25.08.2013

III 500 December 2014 Synchronized on 28.02.2014

NTPL (JV Company of NLC & TANGEDCO)

Tuticorin I 500 Original schedule:

40 months after

LOA

Anticipated

schedule:

February 2015

LOA signed on 28.01.2009

Unit ready for synchronization.

II 500 Original schedule:

45 months after

LOA

Anticipated

schedule:

March 2015

LOA signed on 28.01.2009

Unit ready for synchronization.


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 42 months from

Zero Date (2018-

19). Subsequent

units at six months

interval.

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 Following are major thermal plants coming up in Southern Region during 12th

Plan :

Sl

No.

Name of project Located in Owner Capacity

in MW

Remarks

1 Krishnapattnam JV Andhra Pradesh State 1600 U-I: Dec.14

U-II: Mar 16

2 Rayalaseema TPS ST-IV Andhra Pradesh State 600 Aug. 16

3 Meenakshi PH-II Andhra Pradesh IPP 700

4 Simhapuri PH-II Andhra Pradesh IPP 150

5 East Coast Energy

Thermal Andhra Pradesh IPP 1320 AP : 300 MW

6 Thermal Powertech. Andhra Pradesh IPP 1320 AP : 500 MW.

PPA signed.

7 NCC Krishnapattnam Andhra Pradesh IPP 1320 AP : 250 MW

8 Hinduja State IPP, Vizag Andhra Pradesh IPP 1050 Mar 2015

9 Bellary TPS U-3 Karnataka State 700 Mar 2015

10 Yeramarus TPS Karnataka State 1600 Mar 2015. No

connectivity at 400 kV

level for startup power

11 Edlapur Karnataka State 800

12 Coastal Energen Tamil Nadu IPP 1200 U-I: Trial run would

be over in few days

U: By April 2015

13 Ind-Barath Power Tamil Nadu IPP 660

14 IL&FS Tamil Nadu IPP 1200 New Environmental

Clearance under

process

15 Kakatiya TPP ST-II Telangana State 600 August 2015.

16 Singareni Telangana IPP 1200 U 1Oct 2015

U2 Dec 2015


6.2 The following had been noted in the TCC Meeting:

KPCL had requested startup power for Yeramarus TPS by tapping 400

kV Raichur – Gooty lines of PGCIL.

KPTCL had informed that startup power for KPCL’s Yeramarus unit

was required at 400 kV level. Tapping/LILO of Raichur - Gooty lines

had been suggested and the matter taken up with CTU.

SRLDC and PGCIL had opined that such type of scheme may not be

feasible as per Regulations. Margins available for downward transfer of

power may also get affected in case other evacuation lines did not come

up and this is used as injection of power also.

It was noted that Hon’ble CERC was already hearing a Petition

regarding LILO arrangements.

KPCL was suggested to take up the matter with the Standing Committee.

SRLDC had stated that Unit 3 of Bellary TPS should come with the

required evacuation system.

6.3 In the Meeting, KPCL requested startup power for Yeramarus TPS from ISTS as an

interim measure, since the plant was in urgent need for startup power to meet certain

deadlines. 400 kV switchyard was ready along with station transformer. The planned

evacuation line (STU) was yet to be commissioned.

6.4 Director (Tr.), KPTCL informed that the time line had been recently been advanced

and existing ISTS line (400 kV Raichur – Gooty lines) was closer to the plant.

6.5 The Committee observed that 400 kV Raichur – Gooty line was a vital link for import

of power from NEW grid. Besides, there were protection issues etc that were

involved, Petition regarding LILO arrangement etc was already before Hon’ble

Commission. KPCL was therefore advised to take up the matter appropriately with

the Standing Committee on Power System Planning.

7. COAL STOCK POSITION IN THERMAL STATIONS OF SOUTHERN REGION

7.1 Coal stock position had remained critical in APGENCO stations, Simhadri,

Ramagundam, RTPS, BTPS and at NTECL station during the period under review.

Chairperson, SRPC vide letter dated 01st August 2014 (Annexure-VIII) addressed to

Secretary (Power) had taken up this matter.


It was noted that the coal stock position at Vijayawada, Rayalaseema, Raichur

& Tuticorin Thermal Stations remained critical. NTECL was also having

critical coal stock position and Unit-III was also coming up.


NTPC had informed that presently coal stock at Ramagundam and Simhadri

was adequate for 12 & 16 days of generation respectively. NTECL was facing

some problems in the pipe conveyor which was out for the past 8 to 9 days or

so. The same was likely to come back before 20th

December 2014. Coal for 3rd

Unit had been tied up and once ‘Consent for Operation’ is received MCL would

commence the supply. Blending with imported coal was being carried out.

However, the realization from MCL for Vallur remained at around 70 % only.

TSTRANSCO had stated that the coal stock position especially in CGS needed

to be augmented keeping in view the peak months ahead.

7.3 In the Meeting, GM (S & M), MCL informed that on account of enhanced coal

production in MCL, the generating plants were in receipt of more coal as compared to

previous year. The offtake of coal had increased to 86 MT as compared to 76 MT last

year. However, sufficient Railway wagons were not available and there was stagnation

also in some sections. He also mentioned that as per MoEF guidelines, for 1st January

2015 to June 2016, all power plants had to ensure that they maintained weighted average

ash content of 34 % on a quarterly average basis. In this regard, power plants need to

make their own arrangements with the help of nearby washeries etc. so as to maintain

ash content as stipulated. Most of the plants had represented that they were maintaining

34 % through blending with imported coal etc. However, MoEF had stipulated that

during movement itself the average ash content must be within 34 %.

7.4 It was noted that the issue of 34% ash content had been discussed in earlier SRPC

Meeting wherein it was observed that with blending of imported coal, power plants

could ensure ash content as stipulated.

7.5 MCL informed that materialization for Vijayawada was about 60 % till November 2014

which had increased to 73 % during December 2014 (upto 17th

) KPCL, Raichur

materialization was more than 100 %. NTECL, Vallur materialization was 64% up to

November 2014 and had gone up to around 78 % during December 2014 (upto 17th

).

NTPC Simhadri materialization was around 72% while that of Kaniha was around 95 %.

There was adequate coal stock ,and facility for daily loading 50 rakes at Talcher and 35

rakes at Ib valley existed with MCL. However, they were getting only 37 rakes in

Talcher and 24 rakes in Ib. He requested the generating companies to take up this

matter with Railway. 100 % offer to the generating plants was being made by MCL as

per the plan.

7.6 TSGENCO opined that a dedicated corridor was required in view of number of thermal

plants coming up in the Region. The requirement for indigenous as well as imported coal

would only increase in the future.


7.7 APGENCO expressed concern that only 65% of ACQ was being received by APGENCO

plants. In view of the poor coal stock in the stations, the only recourse would be to shut

down the units in the event of any unforeseen disruption in the coal transportation.

7.8 NTECL mentioned that both MCL and Railways jointly need to identify measures to

ensure adequate coal supply to plants which would in turn ensure power to end

consumers. 85 % PLF could not be maintained with just 65-70 % coal availability.

Hence, MCL & Railways could have a joint Meeting to address the issue appropriately..

7.9 Regional ED (South), NTPC said that Simhadri was requesting coal supply more than

ACQ. However, the supply was only around 65 % of the ACQ itself.

7.10 GM (S& M), MCL stated that request for coal more than ACQ was to be furnished in

the appropriate format.

7.11 Chairperson, SRPC suggested that the issues regarding coal transport be again taken up

with MoP keeping in view the long term sustainability of thermal plants.

7.12 After deliberations, the following was agreed:

Chairperson, SRPC would once again take up the issues regarding dedicated

Railway corridor, strengthening of stagnated sectors, automated signaling

system etc. with MoP.

A joint Meeting with MCL and Railways at Bhubaneshwar could be arranged.

8. SIMHADRI STPS – SCHEDULES FOR 12-10-2014 TO 25-10-2014

8.1 ‘Hudhud’ cyclone had affected generation in Simhadri STPS complex on account of

outages of major evacuation lines. Due to outage / limitations in the transmission

system, SRLDC had regulated generation from Simhadri STPS in real time based on the

line loadings etc. A Meeting of APSLDC, TSSLDC, SRLDC, NTPC & SRPC

Secretariat was held on 05th

November 2014 in NTPC, Secunderabad to discuss issues

relating to schedules of Simhadri STPS for the period from 12.10.2014 to 25.10.2014

(Record Notes of discussions available at www.srpc.kar.nic.in/website/

2014/meetings/special/rcn05-11-14.pdf).

8.2 The matter was further deliberated in the 26th

Meeting of Commercial Sub-Committee

held on 21st November 2014. After deliberations, the following had been agreed:

Revision of Generation schedules of Simhadri STPS to actual generation for all

time blocks from block No.34 of 12th

October 2014 to block No.88 of 25th

http://www.srpc.kar.nic.in/website/


October 2014. Scheduled drawal of beneficiaries of Simhadri STPS Stage-II

would also be revised accordingly.

Revision of Generation schedules of Talcher STPS Stage-II for the blocks 39 to

61 for 12th

Oct 2014 with actual.

Exemption from Hon’ble CERC needs to be obtained by AP SLDC in respect

of control area of Simhadri STPS Stage-I.

In respect of schedules of Simhadri STPS Stage-I, APSLDC, TSTRANSCO &

NTPC to discuss and settle the matter separately.

In order to consider matter regarding deemed DC, NTPC needs to document

details of problems faced in synchronization of units. Coal stock position

during 12th

October to 25th

October 2014 also needs to be furnished.

Details would be put up to ensuing TCC/SRPC for kind consideration.

8.3 Subsequently NTPC vide letter dated 25th

November 2014 (Annexure-IX) had

furnished the details.


PCKL had opined that this appeared to be a ‘Force Majeure’ condition under

‘Act of God’ and deemed DC could not be allowed. APTRANSCO stated

that the provision of the Regulations needed to be followed. KSEB observed

that deemed DC could be allowed for this case. TANTRANSCO observed

that this being a genuine ‘Force Majeure’ condition, the same could be

accepted as a onetime measure. TSTRANSCO stated that deemed DC of

past month (excluding any planned outages) could be allowed. SRPC

Secretariat opined that as per Regulations, this was a ‘Uncontrollable

Parameter’ which could be compensated during Truing Up Exercise in

accordance with CERC (Terms & Conditions of Tariff) Regulations. It was

also pointed out that this was liable to be quoted as precedence for any ‘Act

of God’ instances in future.

NTPC had stated that this was an ‘Act of God’ and deemed DC should be

allowed as natural justice. Fixed charges were recoverable at 83% availability

and Simhadri II was likely to cross 83% availability by year end. The issue

was more relating to ‘Principle’, since there would be no financial gains or

loss either to any of the beneficiaries or to NTPC. Payment of Incentive was

based on PLF and not on availability. NTPC also pointed out that similar

clause for deemed availability existed in respect of transmission elements.

Further, during transmission constraints (like Talcher-Kolar pole tripping)

deemed DC was already being accorded to Talcher – II units. A similar

treatment was being sought in this instance.

After deliberation, TCC had recommended that Deemed DC be allowed for

Simhadri II for the period from 12th

October 2014 to 25th

October 2014 as a

“one time” measure without citing this precedence in future. Deemed DC for

the affected period would be based on the average DC of Stage-II Units for

the period 5th

October to 11th

October, excluding any planned outage. The

following was also agreed:

Revision of Generation schedules of Simhadri STPS Stage-II to

actual generation for all time blocks from block No.34 of 12th

October 2014 to block No.88 of 25th

October 2014. Scheduled


drawal of beneficiaries of Simhadri STPS Stage-II would be revised

accordingly.

Revision of Generation schedules of Talcher STPS Stage-II for the

blocks 39 to 61 for 12th


Exemption from Hon’ble CERC was needed to be obtained by AP SLDC in

respect of control area of Simhadri STPS Stage-I (scheduling aspects).

8.5 The Committee approved the following:

Deemed DC for Simhadri STPS Stage-II for the period from 12th

October

2014 to 25th

October 2014 as a “one time” measure without citing this

precedence in future. Deemed DC for the affected period would be based on

the average DC of Stage-II Units for the period 5th

October to 11th

October,

excluding any planned outage.

Revision of Generation schedules of Simhadri STPS Stage-II to actual

generation for all time blocks from block No.34 of 12th

October 2014 to block

No.88 of 25th

October 2014. Scheduled drawal of beneficiaries of Simhadri

STPS Stage-II would be revised accordingly.

Revision of Generation schedules of Talcher STPS Stage-II for the blocks 39

to 61 for 12th


9. EMERGENCY RESTORATION SYSTEM (ERS)

9.1 Need for ERS had been felt during the recent “Hud Hud” Cyclone. In this regard CEA

had taken a Meeting on 10th

November 2014. In the Meeting it was noted that PGCIL

was having 2 ERS (1 at Vijayawada & 1 at Bangalore) in Southern Region. KPTCL had

also reported availability of ERS. APTRANSCO was planning to procure ERS.

9.2 Requirement of ERS is mandated as per Regulation 22 of CEA (Grid Standards)

Regulations 2010 as given below:

“Each transmission licensee shall have an arrangement for restoration of transmission

lines of 400 kV and above and strategic 220 kV lines through the use of Emergency

Restoration System in order to minimize the outage time of the transmission lines in case

of tower failures.”

9.3 PGCIL vide letter dated 4th

December 2014 (Annexure-X) had stated that considering

the massive cyclone that had hit Andhra Pradesh in October 2014 disrupting power

supply over considerable areas, the earlier proposal of procurement of ERS substations

be reconsidered, to take care of any such contingencies in future.



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. KSEB enquired whether it could be funded through PSDF.

APTRANSCO informed that in the recently held Meeting on ERS at CEA it

had been pointed out that funding through PSDF may not be possible.

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

process.

TCC recommended for procurement of one set of 400/220/33 kV ERS

Substation for Southern Region by POWERGRID. It was also suggested that

PGCIL may endeavor to get it funded through PSDF.

9.5 Director, APTRANSCO informed that 400 kV ERS towers could also be deployed at

lower voltages also. Considering the vast extent of 400 KV network available, it would be

prudent to go for procurement of 400 KV ERS system. .The Cost for 16-17 towers ERS

was about Rs 23 Crores.

9.6 In the Meeting, on a query regarding funding from PSDF, it was clarified that as noted in

the Meeting taken by CEA on 10th

November 2014, utilities would need to procure ERS

from their own funding.

9.7 The Committee 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.

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 March 2015.

Foundation issues

in Switchyard.

Reactor is ready.

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 May 2015

Davanagere By January 2015

Nelamangala By May 2015

Talaguppa By March 2015

Guttur Line Reactor By April 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 80/125

21st

SRPC/

34th

SC

Bus By Feb

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

TCC

suggested

implementi

ng 2x 125

MVAR in

line with

SC

decision.


PGCIL had informed that the reactor at Hyderabad had been dropped in view of the

STATCOM being planned at Hyderabad. It had been suggested that PGCIL may revert

back with ratification/approval of Standing Committee in this regard.


TSTRANSCO had informed that 125 MVAR reactor at Malkaram had been

planned. However, PGCIL was planning to convert the line reactor of

Malkaram-Hyderabad line (at Hyderabad) as switchable line reactor. Hence,

need for the reactor at Malkaram needed to be ascertained. In case not

required, TSTRANSCO would divert the same to some other high voltage

node. CTU stated that they would revert back after studying the same.

Regarding 2 x 125 MVAR, reactors at Kaiga, NPCIL had stated that they were

agreeable for one reactor and approval process had been initiated. Regarding

2nd

reactor they had sought clarifications from CTU and reply was awaited.

CTU had clarified that necessary technical justification had already been

furnished to NPCIL. Further, the Standing Committee had already approved

2x125 MVAR reactors at Kaiga. SRLDC reiterated that NPCIL, Kaiga should

initiate action for both the reactors. TCC had suggested that Kaiga implement

the recommendations of the Standing Committee at the earliest.

10.3 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

10.4 Construction of 400 kV Vijayawada-Nellore Ckt-III & IV lines under system

strengthening was underway. Along with this, 2 reactors of 63 MVAR at Nellore and

2 reactors of 50 MVAR at Vijayawada are envisaged for both the lines. The reactors

were ready for commissioning at both the ends. During discussions in the OCC

forum it was proposed to utilize above reactors at both the stations even before the

lines are commissioned. SRLDC had opined that utilization of these reactors would

help in containing the high voltage and thus help system operation. In this regard,

letter dated 18th

September 2014 (Annexure-XI) had been addressed to the SRPC

Members.


10.5 In the TCC Meeting, PGCIL had suggested that a regional pool of spare bay equipment

be maintained in view of natural calamities taking place.

10.6 The Committee noted the above.

11. STUDY GROUP OF SLDCs TO ASSESS TTC/ATC AND OPERATIONAL

PLANNING

11.1 Need for having quality node wise data from constituents for optimal utilization of

transmission assets has been felt in various forums. Having a dedicated study group in

SLDCs for TTC/ATC/Operational Planning would help in addressing this issue to a

large extent. Procedure for Relieving Congestion In Real Time Operation mandates

SLDC to assess the TTC/TRM/ATC on its inter-state transmission corridor considering

meshed intra-state corridor for exchange (import/export) of power with ISTS. In

addition, SLDCs are also to designate Main and Alternate Officers as Reliability

Coordinator(s). The need for having dedicated system group in each utility and Load

Despatch Centres for operation planning had also been discussed in MoP Meeting held

on 11th

March 2014 to discuss Task Force Report on Power System Analysis Under

Contingency.

11.2 A Meeting of the Study Group of the SLDCs was held on 20th

October 2014 (Minutes

available at www.srpc.kar.nic.in/website/2014/meetings/special/rnsldc 20-10-14.pdf).

Manpower crunch had been highlighted by most of the SLDCs to handle these

additional responsibilities effectively. AP & Telangana SLDCs were yet to form a Study

Group at the SLDCs. Subsequently a workshop was also organized by SRLDC on 20th

November 2014.

11.3 Considering lower temperature limit (less than 45⁰C) for ATC computation (Kolar-

Hosur D/C line) was under examination of NRCE.


MS, SRPC had informed that draft guidelines which included ambient

temperature based TTC, SPS etc. had been prepared and were under

circulation. All constituents except AP & Telangana had furnished the data

for TTC purpose. Further, Main & Alternate Reliability Coordinators were

to be nominated by each SLDC as per provision of the Congestion

Regulation.

APTRANSCO & TSTRANSCO expressed that there were manpower issues

on account of bifurcation. Therefore, they required some more time for

streamlining the activities. SRLDC/SRPC/other constituents suggested that

one or two Officers could be nominated to carry out the mandated activities.

http://www.srpc.kar.nic.in/website/2014/meetings/special/rnsldc%2020-10-14.pdf


SRLDC had pointed out that SLDCs were raising issue of manpower

shortage and this needed to be highlighted in the SRPC Meeting.

After deliberation, the following was agreed:

AP & Telangana SLDCs would communicate the nominations.

SRLDC would guide/assist AP and Telangana SLDCs in arriving

node-wise data for two months period and subsequently AP &

Telangana SLDCs would take over the exercise.

TCC had recommended strengthening of SLDCs in terms of

manpower.

Main & Alternate Reliability Coordinators to be nominated at each

SLDC. It was noted that NLDC and SRLDC had the same in place.

11.5 In the Meeting, ED, SRLDC suggested that AP & Telangana may entrust the works to

suitable available Officers for the purpose. However, in the absence of node wise data,

the existing practice of ATC/TTC computations would be continued by SRLDC.

11.6 Chairperson, SRPC noted that other states had identified Officers who were able to

submit the required data. Similarly, AP & Telangana could also kindly identify one or

two Officers to carry out the above activities.

11.7 CMD, TSTRANSCO assured that they would arrange necessary action in this regard.

11.8 APTRANSCO also assured that they would ensure needful action.

12. SEMs ON ALL FEEDERS FOR SECTIONAL LOSSES

12.1 SRLDC had put this issue to Commercial sub- Committee of SRPC as follows:

“As per CEA (Installation and operation of meters) Regulations, 2006 and

Amendment thereof,

7.1 At one end of the line between the sub-stations of the same licensee, and

at both ends of the line between sub-stations of two different licensees.

But in the backdrop of increased complexities in Transmission network, a need is felt

for installing the SEMs on both ends of all the feeders of same licensees also

irrespective of ownership. This will help in computing Sectional Loss at each bus and

identify the metering deficiencies and under-recordings. Commercial Committee may

please approve the proposal so that CTU can do the needful. ”

12.2 This issue had been discussed in the 25th

Meeting of Commercial Sub-Committee of

SRPC. After deliberations, Commercial Sub- Committee had agreed in principle, but

observed that installation of SEMs on all feeders involved considerable cost implications

etc. Hence it was agreed that the details of SEMs requirement etc would be furnished by

SRLDC so that the matter could be put up to TCC/SRPC for consideration.


12.3 SRLDC letter dated 17th

December 2014 furnishing the details of transmission lines

where SEMs ( 51 nos) are to be installed is at Annexure-XII


MS, SRPC had said that SRLDC was facing a number of issues relating to

timely receipt of data, validation of data etc. As highlighted by SRLDC,

provision of the SEMs would help in computing Sectional Loss at each bus

and also in identification of metering deficiencies and under-recordings. The

total cost would be around Rs 10 lakhs.

TCC had recommended the scheme for approval. SEMs would be provided

by respective utilities. Cost of SEMs which would be provided by PGCIL,

would be shared as per the existing sharing mechanism.

12.5 The Committee approved installation of SEMs by respective utilities on both ends of

all the feeders of same licensees as per Annexure XII. Cost of the SEMs would be

shared as per the Regulations.

13. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION

13.1 Automatic Demand Management Schemes

13.1.1 Automatic Demand Management Scheme in line with clause 5.4.2 (d) of the IEGC

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.

13.1.2 The following is the status update on the action finalized in the 25th

Meeting of SRPC:

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. Other Constituents (other than KSEB) also needed to put the

ADMS in place.

Scheme in TN yet to be implemented. In 101st OCCM TN had

informed that the scheme would be completed by December 2014.

The logic would take care of sudden withdrawal of wind

generation also.

KPTCL had informed that 350 MW loads had been identified for ADMS.

Initially the loads would be tripped manually, but within a period of three

months, the same would be automated.

Scheme in Karnataka yet to be implemented. In the 101st OCCM

Karnataka SLDC had informed that the scheme would be completed

by December 2014.


AP & Telangana had informed that the new upgraded SCADA system

was likely to be in place by October 2014 and ADMS would be

subsequently implemented.

Scheme in AP & Telangana yet to be implemented. In the 101st

OCCM AP &TS SLDCs had informed that the scheme would be

completed by March 2015.

KSEB had informed that the scheme (320 MW) had already been

implemented.

New Scheme (which would replace the old implemented scheme) at

11 kV was being implemented.


APTRANSCO & TSTRANSCO had informed that ADMS would be taken

up after completion of SCADA up-gradation works expected in March

2015. It may take around 2-3 months’ time after completion of SCADA

up-gradation works.

KPTCL had informed that existing SCADA had facility of tripping at

66/110/220 kV level from the SLDC. The scheme would be under trial

operation upto 31st March 2015. Subsequently, it would be put in regular

operation from 2nd

April 2015. DISCOMs were also being involved and

trippings sought to be carried out at 11 kV level so as to mitigate large

scale interruptions to consumers.

TANTRANSCO had informed that they would implement the scheme

along with the new SCADA ( February 2015). SRLDC/SRPC pointed out

that ADMS/Contingency Scheme for Tamil Nadu was further mandated in

a CERC Order. As per the Order, monthly status report was also to be

submitted. Hence, TN needed to complete this scheme at the earliest. The

scheme should also take care contingency of sudden withdrawal of wind

generation.


13.2 Inadequate UFRs and df/dt reliefs

13.2.1 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.


13.2.2 Visible relief of the states is as follows :

AUFR, df/dt feeders Percentage relief realization w.r.t. SCADA monitored

October 2014 August 2014

MAX MIN AVG MAX MIN AVG

AP 58% 15% 40% 109% 50% 82%

TS 123% 39% 77%

KAR 75% 16% 55% 83% 7% 59%

KER 106% 52% 74% 80% 23% 48%

TN 69% 21% 53% 74% 47% 60%

SR 87% 49% 70% 80% 47% 65%

Except Kerala and Puducherry all the other constituents were yet to

implement the additional feeders

All the constituents were yet to complete 100% SCADA mapping. KSEB

had approached CERC for time extension for complete the activity.

13.2.3 In the 24th

Meeting of TCC SLDCs had been requested to examine the matter in

consultation with the Discoms. Endeavour to improve the relief figures by about 20 %

(at least up to 70 %) would be ensured by the next SRPC Meeting.

The issue is being regularly monitored in the OCCM but there was no

significant improvement from the earlier visible relief.


Updated status of the visibility and installation with respect to the

recommended quantum was presented (Annexure-XIII). It was noted that

since last Meeting of TCC, KPTCL had improved both visibility as well as

quantum of UFR. However, the visible relief was still hovering in the range

of 60 -70%.

After deliberation, the following was agreed:

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.


13.3 Low Voltage and installation of UV Relay/High voltage

13.3.1 Following is the status on the actionable points as discussed in the 24th

TCC Meeting:

KSEB had finalized the scheme which had been put to higher management

and approval was awaited.

Scheme was yet to be approved and implemented

SRLDC had said that this issue was being followed up since last couple of

years and they may be constrained to go for physical regulation measures

in low voltage areas.


Scheme had been finalized and implemented

KPTCL had agreed to implement UV relay scheme. In addition steps

would also be taken to provide capacitor of adequate capacity at low

voltage nodes.

Scheme was yet to be approved and implemented

TANTRANSCO had stated that they would maintain the voltage levels

within limits at 230 kV level and below. It had been pointed out that loss

of wind generation had taken place due to low voltage scenario. States

were to maintain voltages within IEGC range and in case voltages are not

maintained, then UVR is to be provided as per IEGC.

IEGC/CEA Regulations mandate providing UV relays if need arises.


SRLDC had expressed concern that despite earlier agreeing for the

implementation of UV Relays, KPTCL and TANTRANSCO had not shown

any progress in this regard. Installation of UVR was mandated in IEGC as

well as CEA Regulations.

MS, SRPC had said that the analysis of low voltage nodes had been carried

out. Some of the nodes like Gazuwaka, Palakkad, Somanahalli, Udumalpet,

Trichur etc. were facing low voltages at different periods. Activation of UV

feature in relays would only help strengthen the safety net and aid system

operation. In case in future, voltage profile improved on a sustained basis,

this feature could be recommended for disabling.

TANTRANSCO had informed that system strengthening and capacitor

installation had helped improve the voltage profile in the state and thus there

may not be any need for installation of UVR. However, TN would

implement/enable UVR at identified low voltage nodes.

KPTCL had pointed out that the voltage profile in and around Bengaluru had

improved due to rectification of faulty capacitor banks and also installation

of new capacitors. All zones were concentrating to improve voltage profile

at distribution level. SRLDC had pointed out that voltage at Somanahalli had

touched 378 kV a couple of days back. After discussions, KPTCL agreed

that to implement/ enable UV Relay. The same would under trial operation

upto 31st

March 2015 and would be implemented by 2nd

April 2015.

KSEB had informed that the scheme had been sanctioned by their

Management and the same would be implemented in about a months’ time.

PGCIL had expressed concern that number of failure of their equipment had

taken place due to sustained high voltage operation and delayed opening of

elements at high voltages. In case any pattern was known, it may be prudent

to take out elements a little earlier rather than switching it off at high

voltage. It was also suggested that analysis of high voltage nodes in the

Region could also be made in the next Meeting. This exercise would help in

assessment of additional reactor requirements and also focus on short term

operational measures to be undertaken.



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

MVAR Interchange

13.4.1 In the 25th


All GENCOs would endeavor to ensure RGMO response as mandated in

the Regulations.

Response would be analyzed further in a Special Meeting of Generators to

be held during August 2014.

Regarding MVAR, the constituents had been requested to kindly comply

the decisions taken in various Meetings in this regard.

A Meeting in this regard was held on 27.08.2014 (Minutes available

http://www.srpc.kar.nic.in/website/2014/meetings/special/

Minutes_RGMO.27.08.2014.pdf)

The response was minimal by most of the generators and there was

considerable scope of improvement.

Actionable points in respect of RGMO and MVAR finalized in the

Special Meeting needed to be implemented.

All the SLDCs to monitor the response of the generators in their

control area and take up the matter with respective SERC in case of

lack of response or inadequate response. (RoP dated 06.07.2014 on

Petition No.302/MP/2013)


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

of their control area.

Each Genco to identify one station which would be monitored for RGMO

performance with the objective of improving the performance.

Other Units would also endeavor to improve their performance

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

to SLDC/SRLDC.

A separate Committee had been formed by Hon’ble CERC to look into

associated issues with regard to implementation of RGMO/FGMO.

13.4.3 In the Meeting, the 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

13.4.4 It was noted that all other generators too needed to ensure RGMO response as

mandated in the Regulations.

http://www.srpc.kar.nic.in/website/2014/meetings/special/


13.4.5 ED, SRLDC pointed out that RGMO status needed to be ensured to SLDCs/RLDCs.

Categorization of performance as negative response, inadequate performance and

adequate performance was already been carried out. With regard to Central Sector

Stations, this would be one criteria for certification of performance as per CERC Terms

& Conditions of Tariff Regulations. Also, the duration between any instance of

nonperformance to instance of next performance would be considered as non-

performance.

13.5 Low Voltage Ride Through (LVRT)

13.5.1 The following had been noted in the SRPC/TCC Meeting:

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

1,000 MW in the past one year. This was on account of non-availability of

LVRT feature which was 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. Data/information

could be jointly studied to assess the root cause for such incidents, whether it

could be attributed to variability or on account of non-availability of

LVRT/FRT features

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.

After deliberations, it had been decided that NLDC would carry out bilateral

discussions/study with Tamil Nadu.

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

13.5.3 In the TCC Meeting, TANTRANSCO & KPTCL were requested to kindly initiate

necessary action in this regard.


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

13.6.1 Each SLDC was to create 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.

A Meeting was held with GETCO SLDC so as to be acquainted of the load

forecasting being carried out in Gujarat. (Minutes available at http://www.srpc.kar.nic.in /website/2014/meetings/special/rnspl23-08-14.pdf)

13.6.2 SRLDC/SRPC Secretariat had expressed concern that Regulatory requirements had

not been met since the scheme was to be put in place by 01.01.2011. They had

requested all the constituents to initiate necessary steps in this regard.

13.7 Sudden Change in Demand / Frequency Excursion

13.7.1 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.

Another Meeting in this regard was held on 26th

September 2014 (Minutes

available at http://www.srpc.kar.nic.in/website/2014/ meetings/special/rn26-09-

14.pdf)

Constituents to initiate action as finalized in the Special Meetings.

13.7.2 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.

13.8 Arranging of interruptible loads in four groups

13.8.1 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.

13.8.2 SRLDC/ SRPC Secretariat had requested for necessary compliance since regulatory

requirement were not being fully met.

http://www.srpc.kar.nic.in/

http://www.srpc.kar.nic.in/website/2014/


13.9 Follow up by MoP on implementation of corrective action

Ministry of Power had convened a Meeting to discuss various issues such as

implementation of corrective action based on 3rd

Party Audit of Substations,

implementation of RGMO, operation of Defense Mechanism, Ring Fencing of

SLDCs, formation of dedicated system studies group etc. In this regard,

Chairperson, SRPC had also addressed a letter dated 7th

August 2014 (Annexure-

XIV) to SRPC Members.

13.10 PSS Tuning

13.10.1 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 25th

SRPC Meeting it was noted that in the

Meeting taken by Secretary (Power) 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.


In a Meeting held in MoP, the responsibility of PSS tuning had been

entrusted to CTU. Earlier too in the 25th

Meeting of SRPC, CTU had been

suggested to take up any issue in this regard appropriately.

CTU had assured that they would take up this issue appropriately.


13.11 Other Issues requiring kind attention of SRPC/ TCC

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

SRPC, and merit kind attention:

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.

Reactive Power Planning including at distribution level needs to be

submitted to CEA with a copy to SRPC Secretariat.

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, Sewa Bhavan, New Delhi-110066. Report on Physical

Security, other Mock Drills for CMP, Mock Drill for Black Start Restoration

is to be furnished to Chief Engineer, DMLF, CEA, Sewa Bhavan, New

Delhi-66. Copy of the report is to be sent to SRPC Secretariat

([email protected] and [email protected]).

mailto:[email protected]

mailto:[email protected]


Tertiary Transformer at HVDC Bhadravathi was planned to be

commissioned by December 2014. Same needs to be commissioned as per

schedule since number of instances of pole blocking due to auxiliary supply

failure have been experienced.

Pollution mapping activities like installation of dummy insulators and six

reading within interval of 4 months are being undertaken.

Transmission elements outage planning to be done in a coordinated manner

and shutdown requests to be received by 3rd

of each month for the next

month.


MS, SRPC had informed that in the 102nd

Meeting of OCC held on 10th

December 2014, CEA, NTPC, NHPC & PGCIL had made Presentation on

Cyber Security issues. 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.

All the constituents agreed to furnish the nomination of CISO to CEA &

Nodal CERT with a copy to SRPC Secretariat.

Regarding auxiliary power at Bhadravathi HVDC, PGCIL had confirmed

that the tertiary transformer would be commissioned by December 2014.


13.12. Protection Suite

13.12.1 In the Meeting, MS, SRPC informed that the need for procuring Protection Suite had

been deliberated in the Meetings of Protection Sub-Committee of SRPC. The

Protection Sub-Committee had noted that Protection Suite would be an important

tool. It was proposed that the Suite be procured through PSDF funding. He suggested

that all the states may kindly furnish their consent in this regard before the next

Protection Sub- Committee Meeting.

13.12.2 The Committee approved in principle the proposal for procurement of Protection

Suite through PSDF Funding.

14. REVIEW OF PERFORMANCE OF ULDC SCHEME

14.1 The issue is being followed up in the OCC Meetings. Following are the actionable

points in this regard:

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

discussed in the 101st OCC is enclosed as Annexure-XV.

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

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

14.2 In view of difficulty to communicate with Simhadri TPS and other important S/S

during “Hud Hud” cyclone, SRLDC had requested all utilities to maintain reliable

and redundant communication system in place. V-SAT communication may be

required from all critical generating stations, HVDC stations and 400 kV and above

substations.

14.3 APTRANSCO vide letter dated 17.12.2014 (Annexure-XVI ) had proposed

discussion on readiness of SRLDC control room with ALSTOM system and

providing ICCP data to SRLDC/SLDCs.


TSTRANSCO had informed that data validation between SLDC & SRLDC

through ICCCP had been completed. The Service Agreement with M/s. GE

was terminating on 6th

January 2015. However, parallel operation of both the

systems was needed to be in place for three months.

APTRANSCO had informed that the trial run of the ICCP link between

SLDC and SRLDC was underway. The contract with M/s GE was needed to

be extended for three months till the new SCADA system stabilizes.

KSEB had informed that they had earlier agreed for one quarter extension of

the existing AMC and they were agreeable for another three months

extension.

It was agreed that AMC for the existing SCADA be extended for 3 Months

during parallel operation by the respective utilities. ED, SRLDC stated that

presently they were receiving as well as sending the ICCP data. Tuning was

needed to be carried out both by SRLDC and SLDC to ensure that the data is

correct.

MS, SRPC had highlighted the need for V-SAT and SAT Phone

communication keeping in view the communication issues faced during/after

the recent ‘Hud Hud ‘cyclone.

KPTCL had informed that CEA had called a Meeting on communication

issues wherein it was noted that V-SAT communication was the fastest. It

had been suggested to have V-SAT equipment at strategic locations which

could be moved to affected areas quickly.

NTPC had informed that they were getting one set of Satellite Phone at

SRHQ which could be deployed at any of their station.

After deliberations, constituents were suggested to ensure availability of V-

SAT/SAT Phones at strategic locations which would help in effective

communication during disasters.



15. PENDING ARREARS PAYMENT BETWEEN BENEFICIARY STATES IN SR

15.1 The following had been noted in the 25th

Meeting of SRPC:

It was agreed that KPTCL/PCKL and TANTRANSCO would settle this

issue bilaterally. It was also agreed that AP, KPTCL/PCKL and KSEB

would settle the issues bilaterally

APTRANSCO had stated that it had already rejected the claims in respect of

frequency linked penalty/incentive scheme along with valid reasons. This

issue would be resolved bilaterally and was not to be included as agenda in

SRPC meeting.

KSEB/TANTRANSCO had stated that since this issue was not getting

resolved bilaterally, it had been brought to SRPC forum.

TANTRANSCO had stated that SRLDC was the designated agency for

frequency linked penalty/incentive scheme and hence it should provide

necessary data for settling this issue.

SRLDC had informed that in respect of frequency linked penalty/incentive

scheme SRLDC was not in a position to provide any data except for the

month wise summary of the payables and receivables. The hourly data and

computation were stored in floppies which became unusable over a period of

about 20 years. This had already been informed earlier.

Chairperson TCC had suggested that a separate Meeting be convened and

SRLDC provide necessary guidance in this regard.

15.2 Subsequently, this issue had been further deliberated in 25th

& 26th

Meeting of

Commercial Sub- Committee of SRPC.

15.3 TANTRANSCO vide letter dated 29th


that KPTCL has to pay an amount of Rs.26,49,88,513/- to TANGEDCO towards

monetary compensation claims for the period from December 1998 to March 2001. It

had also been stated that status on the above be expedited by KPTCL, PCKL officials.


November 2014 (refer Annexure-II ) had also

stated that regarding frequency linked penalty/incentive scheme for

overdrawal/underdrawal of shares, APTRANSCO and KPTCL may furnish suitable

date for their visit to Chennai to participate in a Meeting to resolve the above issue.

Further, the Nodal Agency SRLDC had to forward the invoices sought by KPTCL on

the above issue.

15.5 KSEB vide letter dated 8th

December 2014 (refer Annexure-III) had stated that as on

31st March 2014, the net receivable amount form and KPTCL was Rs.16,09,87,736 and

from APPCC was Rs.15,61,13,679/-. It was also stated that question of limitation act

does not apply.

15.6 In the TCC Meeting, after deliberations, it was agreed that the issue would be

discussed bilaterally between the concerned states. Only in case of non-convergence,


the matter would be put up to the SRPC forum. A Meeting in this regard would be held

on 9th

Jan 2015 at PCKL office in Bengaluru.


16. OUTSTANDING DUES BETWEEN WR & SR

16.1 Meetings between WR & SR Constituents regarding outstanding payments in respect of

energy transactions between WR & SR for the period prior to January 2003 were held at

Mumbai & Bangalore. The sixth Meeting in this regard was held on 28th

October 2014

at Mumbai, where in the following was agreed:

WRLDC would verify the records and furnish the details to WRPC/SRPC

within 15 days regarding the amount transferred from WR UI Pool to WRTS

during the years 2003-04 & 2004-05.

An amount of Rs.1,80,89,611/- is to be transferred to SRTS.WRTS had

transferred Rs.14,57,444/- to SRTS. The balance amount would be transferred

as and when received from WR Constituents. SRTS would credit the amount

transferred by WRTS to SR Constituents towards transmission charges, under

intimation to SRPC.

WRTS and GUVNL would verify their records at the earliest. WRTS would

follow up with other Constituents for early settlement of the issue.

MSEDCL had informed that they had put up a note for approval of the

management for releasing the payment.

GUVNL had informed that as and when the amount is received from Tamil

Nadu and Karnataka, payment would be made to KSEB & Puducherry

proportionately.

CSPDCL had informed that they have to receive payment from Tamil Nadu &

Karnataka. TANTRANSCO and KPTCL to expedite the payment. There was no representation from MPPMCL in the Meeting.


November 2014 ( refer Annexure-II) had stated

that the status of transfer of amount to SR constituents be updated.

16.3 In the TCC Meeting, SRTS-II, PGCIL had informed that an amount of Rs 14,21,844

transferred by WRTS to SRTS had been passed on to the SR Beneficiaries. Balance

would also be passed on to the beneficiaries as and when the same was received from

WR.


17. UNIFORM RATE OF CHANGE OF FREQUENCY RELIEF SCHEME

(df/dt) TO BE ADOPTED THROUGHOUT THE COUNTRY

17.1 Revision of settings of df/dt relays was proposed on account of various reasons such as

integrated operation of NEWS grid, tightening of frequency band etc. TANTRANSCO

had opined that since National Grid is operated as single large grid at one frequency, the


settings to be adopted for load relief schemes such as df/dt etc. should be uniform

throughout the country.



that the status on the above be deliberated.

17.3 The matter regarding revision of df/dt relay settings in Southern Region as well as

uniform settings of df/dt relays in all the Regions had been taken up with Member

Secretary, NPC vide SRPC letter dated 26th

September 2014. (Annexure-XVII)

17.4 In the TCC Meeting, it was noted that the issue had been referred to NPC for uniform

adoption throughout the country.


18. SPS FOR OVERLOADING OF 400 kV KOLAR – HOSUR LINES

18.1 SPS for overloading of 400 kV Kolar-Hosur lines were finalized in the PCC Meeting of

SRPC. The tentative cost for implementation of the proposed SPS scheme is about

Rs.12.5 lakhs. The time for completion of procurement, installation etc. is around 6 to

7 months. In this regard, copy of letter dated 20th

October 2014 from Power Grid is

enclosed as Annexure-XVIII . Since the requirement of the proposed SPS scheme is

felt even after 8 to 9 months, the implementation of this SPS scheme was proposed to

be approved.

18.2 TCC had recommended the implementation of SPS for approval.

18.3 The Committee approved the implementation of SPS for overloading of 400 kV Kolar-

Hosur lines

19. DETAILS OF PENDING REMEDIAL MEASURES DISCUSSED AND

FINALIZED IN PCC

19.1 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. ( Guttur, Srisailam, Kadra/ Kodasalli

etc). Details of remedial measures etc to be complied with in accordance with the

discussions in the Protection Sub Committee is furnished at Annexure- XIX. The same

was needed to be expedited and implemented at an early date.

19.2 In the TCC Meeting, MS, SRPC had informed that remedial measures had been

compiled during the PCSC Meeting and Sub Group visits. He had requested that

recommendations may please be implemented at the earliest.



20. WHEELING CHARGES PAYABLE BY GOA TO KARNATAKA

20.1 KPTCL vide letter dated 6th

December 2014 (Annexure-XX) had stated that the matter

regarding payment of wheeling charges by Goa to Karnataka for wheeling the CGS

share of power from Ramagundam be discussed.

20.2 TCC had noted that the matter was before Hon’ble CERC.


21. UTILIZATION OF TERTIARY WINDING OF ICTS FOR AUXILIARY

POWER SUPPLY IN SUBSTATIONS


December 2014 (refer Annexure-X) had emphasized that

auxiliary supplies in EHV substation is critical for revival of service in contingencies.

It has therefore been proposed that constituents may consider utilization of tertiary

winding of ICTs, wherever available, in a substation for providing auxiliary supply.


PGCIL had informed that they were using the tertiary winding of their ICTs

for auxiliary power supply in substations. As per CEA Regulations, two

reliable and redundant supplies in addition to DG were required and

utilization of tertiary winding would ensure reliable supply. They had

sufficient experience and confidence for active power loading of tertiary

winding. During recent “Hud Hud” cyclone reliable supply could have been

extended at the earliest using the 400 kV lines and tertiary winding.

KPTCL and TANTRANSCO had informed that there had been instances of

ICT failures in case of reactive loading and as a policy they were not

utilizing the tertiary winding.

After deliberation, TCC had recommended that utilization of tertiary

winding would be solely at the discretion of concerned utilities.


22 PROCUREMENT OF 500 MVA ICT AS SPARE INSTEAD OF 315 MVA ICT

APPROVED UNDER RAMAGUNDAM TRANSMISSION SYSTEM


December 2014 (refer Annexure-X) had proposed

procurement of higher capacity ICT since it would be techno-economic in view of

future load growth. It had therefore been proposed to procure 1 No. 400 / 220 kV 500

MVA Transformer instead of 400 / 220 kV 315 MVA Transformer already approved.


TSTRANSCO observed that 315 MVA ICT population was more in the

states and hence procurement of 315 MVA ICT may remain.

PGCIL had clarified that the foundation requirement would be maintained

the same. The reactance would be matched with the existing ICTs for parallel


operation (they had sufficient experience viz, Nagarjunasagar). With

increased growth rates etc PGCIL was going for 500 MVA ICTs and

difference of cost implication between 500 MVA ICT and 315 MVA ICT

was minimal.

TCC had recommended that 500 MVA ICT be procured instead of 315 MVA

ICT under Ramagundam Transmission System.

22.3 The Committee approved procurement for 500 MVA ICT instead of 315 MVA ICT

under Ramagundam Transmission System.

23. PROCUREMENT OF 3x125 MVAR REACTORS INSTEAD OF 3 x 50 MVAR

REACTORS APPROVED UNDER RAMAGUNDAM TRANSMISSION

SYSTEM


December 2014 (refer Annexure-X) had stated that

addition of generation capacity and augmentation of Transmission System in the past

few years has led to increase in short circuit level of the system. Hence, in view of

system requirements and to meet any exigency in the event of failure of 50 MVAR

Reactors in future, it has been proposed that 3 x 125 MVAR Reactors be procured as

spare along with associated switching arrangements instead of 3 x 50 MVAR Reactors

already approved.


SRLDC had noted that the short circuit MVA at nodes like Ramagundam,

Nagarjunasagar etc. had gone up. The impact of 125 MVAR reactor was

presently similar to that of 50 MVAR reactors at earlier short circuit levels. It

was technically justified to go for 125 MVAR reactors. PGCIL also endorsed

the views of SRLDC.

TCC had recommended for procurement of 3x125 MVAR reactors as spare

along with associated switching arrangements instead of 3x50 MVAR

reactors already approved.

23.3 The Committee approved procurement of 3x125 MVAR reactors as spare along with

associated switching arrangements instead of 3x50 MVAR reactors already approved

under Ramagundam transmission system.

24. CONVERTING FIXED LINE REACTORS INTO SWITCHABLE LINE

REACTORS IN OVER COMPENSATED LINES.


December 2014 (refer Annexure-X) had stated that on

account of reduction in line length after LILO at certain nodes, some lines are being

over compensated with existing fixed Reactors. Hence, it had been proposed that fixed

line reactors on the following lines be converted to switchable line reactors:

Malkaram – Hyderabad-II Kurnool – Gooty Simhadri – Gazuwaka II


24.2 TCC had recommended for approval that the above line reactors be converted to

switchable reactors.

24.3 The Committee approved that fixed line reactors on the Malkaram – Hyderabad-II,

Kurnool – Gooty & Simhadri- Gazuwaka 400 kV lines be converted to switchable

reactors.

25. CERC ORDER ON UPCL POWER EVACUATION ISSUE


December 2014 (refer Annexure-III) had stated that the

cost of transmission system used by UPCL is being wrongly socialized among other

DICs. Follow up action in this regard had been sought to be reviewed.

25.2 In the TCC Meeting, it was noted that the issue was being heard by Hon’ble CERC.


26. RE-CONSTITUTION OF THE VALIDATION COMMITTEE UNDER

REGULATION 7(1)(g) (SHARING OF INTER STATE TRANSMISSION

CHARGES AND LOSSES) REGULATIONS, 2010.



Validation Committee constituted under sharing regulations does not have adequate

representation at state level. This is creating difficulties in appraising state pertinent

issues by STU/DISCOMs before Validation Committee. It has hence been suggested

that Validation Committee may have at least one representative from each state. Till

that time, each state may be allowed to represent in the Validation Committee on

rotational basis.

26.2 In the TCC Meeting, MS, SRPC had informed that all the state/utilities were being

invited to the Meeting of Validation Committee.


27. UTILIZATION OF PSDF TO DEVELOP INTER- STATE TRANSMISSION

SYSTEM TO RELIEVE TRANSMISSION CONSTRAINTS.



need for strengthening of ISTS in the country and to relieve the transmission

congestion and associated issues has been emphasized. It has been suggested that CTU

utilize the funds available in PSDF for constructing new transmission system for

providing relief to the congested regions. Further, congestion amount collected from

the utilities be segregated region-wise. Amount collected from each region may

preferably be utilized for developing the transmission system to relieve congestion of

that region.


27.2 In the TCC Meeting, it was noted that segregation of fund region wise was not feasible

and the same had also been deliberated in various forums. Procedure for utilization of

funds had been clearly spelt out and each utility could apply as per their

requirement/assessment.


28. EARLY COMMISSIONING OF 765 kV VEMAGIRI-KHAMMAM-

HYDERABAD-WARDHA TRANSMISSION SYSTEM FOR THE

ENHANCEMENT OF INTERREGIONAL TRANSMISSION CAPACITY

BETWEEN NEW GRID AND SR.


December 2014 (refer Annexure-III) had suggested early

commissioning for enhancement of inter-regional transmission capacity between ER

and SR. The commissioning of these lines was also required for evacuating huge

generation potential in the Vemagiri area in Andhra Pradesh.


TSTRANSCO had suggested revival of the Vemagiri-Khammam-

Hyderabad link since it would provide east to west connectivity.

CTU had clarified that the scheme had been suggested to be dropped in the

37th

SCPSCSR. However, the matter was being heard by Hon’ble CERC.

29 PUBLISHING THE RESULTS OF SYSTEM STUDIES BY CTU IN

COMPLIANCE WITH REGULATION 20 OF THE CERC (GRANT OF

CONNECTIVITY, LONG TERM AND MEDIUM TERM OPEN ACCESS)

REGULATIONS, 2009.


December 2014 (refer Annexure-III) had stated that CTU

has not been following provisions of the said Regulations. The result of system studies

has not been published in public domain nor the information notified as stipulated in

the approved procedure. Hence CTU has been requested to comply with the

procedures stipulated in the Regulation.


KSEB had pointed out that as per the Procedure, CTU needed to publish

TTC/ATC for the coming 3 years along with the study results.

CTU had informed that as could be appreciated there was considerable

uncertainty in the commissioning of generating projects and number of lines

was held up due to RoW issues etc. There were a number of difficulties in the

assessment. The same had also been appraised to Hon’ble CERC. CTU was

adopting a consultative approach in this regard. Study results etc of LTA

Meeting, Special Meeting etc. were contained in the Agenda / Minutes and

were available in the public domain.



30. DIFFERENCE IN COMPUTATION OF CAPACITY CHARGES OF NTPC

STATIONS AS PER CERC REGULATIONS (2014-19)

30.1 In the 24th

Meeting of TCC the following had noted:

KSEB vide letter dated 14th

July 2014 had invited reference to CERC Tariff

Regulation 2014-19 regarding payment of capacity charges to Thermal

Generating Station for a calendar month. It had been stated that all generators

have adopted calculation procedure in accordance with CERC Norms whereas

NTPC has adopted a different methodology for the same. The amount claimed

towards capacity charges by NTPC is more than the amount permissible as per

CERC Norms.

The issue would be first deliberated in the Commercial Sub-Committee.

30.2 Accordingly the issue had been deliberated in the 25th

Meeting of Commercial Sub-

Committee held on 22nd

August 2014. After deliberations, all other beneficiaries, except

KSEB were agreeable for the methodology currently being followed by NTPC.


December 2014 (refer Annexure-III) had stated that NTPC

had adopted a different methodology of their own for calculation of capacity charges

even when CERC has clearly prescribed a method. The amount claimed towards

capacity charges is often more than the amount permissible as per CERC norms.


KSEB pointed out that the provision of Regulations was needed to be followed.

NTPC had stated that this was the common system being followed for all the

stations throughout the country. As can be seen, NTPC was not recovering

any additional amount. In case the suggested system was to be followed,

any post-facto change would result in changes in all the bills for all the

months.

All the other constituents observed that since NTPC was not recovering any

additional amount upto the month, they be allowed to continue with the

existing practice.

It was agreed that this issue would be put up to SRPC for a decision.

30.5 In the Meeting, CE (Tr. & SO), KSEB said that since all other beneficiaries were

agreeable to the methodology being followed by NTPC, KSEB too was agreeable for

the same.

30.6 The Committee noted and agreed for the above.


31. KPTCL DENYING NOC FOR OPEN ACCESS FOR POWER CONTRACTED

FROM UDUPI POWER CORPORATION LTD.


December 2014 (refer Annexure-III) had stated that

KPTCL is denying NOC without any documentary support. Hence based on this

SRLDC had denied KSEB’s application. PPA for 18.5 MW RTC power had been

executed on 9th

April 2014. UPCL had stated that only 90% of the plant capacity is tied

up with ESCOMs of Karnataka and that the 18.5 MW offered to KSEB is not tied up

with any other utility.

31.2 In the TCC Meeting, MS, SRPC had informed that KSEB had filed a petition with

Hon’ble CERC. It would therefore be prudent to await the Order in this regard.


32. DOUBLING OF 110 KV KONAJE-MANJESHWARAM S/C FEEDER


December 2014 (refer Annexure-III) had stated that KSEB

was presently drawing 12 to 15 MW from 110 kV Konaje S/S of KPTCL. The issue

was deliberated in the 35th

SCPSPSR (19.02.2013). Till the 400 kV UPCL- Kasargode

line comes up the above lines could be converted to D/C which would enable more

power to North Kerala.

32.2 In the TCC Meeting, KPTCL had suggested that this issue be also deliberated in the

Meeting to be held at PCKL on 9th

January 2014.


33. PROVISION OF ADDITIONAL SPACE IN SRPC SECRETARIAT / OTHER

CIVIL WORKS

33.1 On account of increase in the number of Member Constituents in SRPC forum, and also

need to conduct a number of Meetings on various issues, it was found necessary to

enhance the available space in the SRPC Conference Hall. Certain other civil works /

modifications were also needed to be taken up in the building. Earlier too, certain

renovation works had been carried out through the good offices of Power Grid and

funding by the constituents. Necessary go ahead in this regard had been kindly sought.

33.2 TCC had observed that the number of member constituents had increased considerably.

It therefore recommended for approval of funding by the Constituents for the additional

space requirement/other civil works in the SRPC Secretariat.

33.3 The Committee approved the same in principle. Details would be put up in the next

Meeting of SRPC.


34 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

34.1 TANTRANSCO vide letter dated 17.12.2014 (Annexure-XXI) had suggested present

S2 region has to be split into two regions namely S2 comprising of Tamil Nadu &

Puducherry and S3 comprising of Kerala alone.


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.

After deliberation, it was agreed that Study Committee could look into the

matter with participation from CTU & NLDC.

34.3 In the Meeting, it was agreed that this issue also would be deliberated in the Study

Committee Meeting with the participation of NLDC, CTU etc..

35. GRID OPERATION

35.1 Grid events/highlights during July 2014

400 kV Thiruvalam – Melakottaiyur ( Kalivanthapattu) D/C Line along with

associated bays under “ Transmission System associated with System

Strengthening of Southern Region XVIII” along with Communication Signal from

sending end to Receiving end, metering, telemetry and protection system had been

successfully charged on 24.07.2014 by PGCIL.

400 kV D/C line with Quad Moose ACSR from Kayathar 400 kV SS to Karaikudi

400 kV PGCIL SS line works completed. One circuit of 195 kms had been

radially test charged from Kayathar end with 63 MVAR 400 kV line reactor at

Kayathar on 04.07.2014 and tied with the grid on 26.07.2014 by TANTRANSCO.

400 kV D/C line from Pugalur 400 kV PGCIL SS to Kalivanthapattu 400 kV SS

line works completed. One circuit of 363.318 Kms had been test charged with 80

MVAR 400 kV line reactor at both ends and tied with grid on 23.07.2014 by

TANTRANSCO.

Conversion of existing 110 kV SC line on SC tower with Leopard conductor from

Loc 1(CBE SS)- 18 of 110 kV CBE O.K Mandapam feeder into 230 kV D/C line

tower with zebra conductor- Line energized on 16.07.2014 by TANTRANSCO

LILO of 230 kV Kayathar- Anuppankulam and 230 kV Kayathar – Pasumalai line

on MC towers at the proposed Kayathar 400 kV SS – Line energized on

19.07.2014 by TANTRANSCO.

Kayathar 400 kV SS was test charged on 04.07.2014 with 1 x 315 MVA ICT by

TANTRANSCO.

Thiruvalam 400 kV SS was test charged with 1 x 315 MVA ICT on 27.07.2014 by

TANTRANSCO.


Coimbatore 400 kV SS was test charged with 1 x 100 MVA auto power transformer

on 16.07.2014 by TANTRANSCO.

Extension of 400/220 kV Thiruvalam S/Stn was commissioned in July 2014 by

PGCIL.

35.2 Grid events/highlights during August 2014

Andhra Pradesh, Kerala & Telangana were additionally allocated 200 MW, 76.83

MW & 100 MW from IGSTPS, Jhajjar of APCPL w.e.f. 1.8.2014 to 31.03.2015.

Operating procedure of SR was released by SRLDC.

Wind mills of capacity 4.7 MW had been added in Tamil Nadu.

35.3 Grid events/highlights during September 2014

Protection Committee Team visit to 400 kV Guttur S/S on 25th

& 26th

September

2014 to study repeated trippings.

Wind mills of capacity 4.9 MW had been added in Tamil Nadu.

MoP vide letter dated 29.09.2014 had allocated 50 MW unallocated power of first

unit (1000 MW) of Kudankulam APP to Andhra Pradesh from the date of

commercial operation of the unit. SRPC vide letter dated 07.10.2014 had

communicated the revised allocation to all the beneficiaries from the date of

commercial operation of the unit 1 of KKNPP.

35.4 Grid events/highlights during October 2014

Sincere cooperation extended by SR constituents during Hud Hud cyclone.

Protection System Analysis Group (PSAG-10) Meeting was held at Srisailam RB

on 14th

& 15th

October 2014 to address the grid disturbances at SRBPH.

200 MW power was additionally allocated to Andhra Pradesh from unallocated

quota of SR from 00 hours of 20th

October 2014 to 19th

November 2014.

35.5 Grid events/highlights during November 2014

Wind Mills of capacity 4.3 MW had been added in Tamil Nadu

35.6 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 30th

November 2014)

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 was sought to be completed early.

36. DEMAND VARIATION (Peak Vs Off-peak)

36.1 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 July 2014 to

November 2014:


Description

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala

Tamil

Nadu Puducherry

Southern

Region

July 2014

Highest 29.89 25.14 33.17 46.16 27.72 32.82 29.90

Date 17th

4th 28th

21st 14

th 1

st 11

th

Lowest 2.55 11.69 14.74 28.89 12.03 13.66 10.68

Date 5th

2nd

4th

5th

20th

27th

5th

Average 19.03 18.20 27.13 40.28 20.03 21.69 16.94

August 2014

Highest 28.97 34.45 36.90 48.50 29.87 48.05 26.33

Date 6th

16th

25th

7th

25th

24th

30th

Lowest 10.36 16.15 18.32 36.42 13.19 13.96 11.25

Date 19th

13th

17th

22nd

3rd

5th

17th

Average 17.53 21.61 29.50 43.11 21.47 26.32 17.07

September 2014

Highest 25.16 33.93 36.55 47.38 28.57 33.78 28.33

Date 11th

16th

8th

1st 8

th 16

th 29

th

Lowest 2.91 13.20 20.20 31.44 8.25 15.40 11.72

Date 30th

18th

28th

27th

30th

2nd

27th

Average 15.06 20.99 29.07 40.40 19.73 25.78 17.80

October 2014

Highest 27.88 30.82 42.79 45.02 35.54 46.78 29.27

Date 12th

12th

27th

8th

24th

27th

28th

Lowest 9.20 15.94 18.82 30.49 9.38 14.68 8.15

Date 14th

17th

19th

5th

2nd

5th

2nd

Average 18.69 22.91 27.57 38.31 19.79 27.89 15.47

November 2014

Highest 22.11 30.19 38.16 47.90 29.22 40.85 26.13

Date 14th

27th

3rd

11th

20th

7th

17th

Lowest 11.29 14.27 19.57 33.61 14.66 25.53 16.67

Date 22nd

2nd

29th

23rd

2nd

16th

9th

Average 16.93 21.88 26.90 40.23 23.16 35.51 20.92

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

36.2 In the TCC Meeting SRLDC had stated that the difference between maximum and

minimum demands were quite high and of the order of 5,000 - 6,000 MW. The same

was required to be minimized through appropriate demand side management in order to

avoid high voltage scenario.

36.3 Constituents were kindly requested to implement suitable DSM measures and also share

information with other constituents for mutual benefit.


37. FREQUENCY OF OPERATION OF SOUTHERN GRID

37.1 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

July 2014 0.11 4.26 33.75 34.06 14.96 12.40 0.47 49.02 49.93

August 2014 0.08 4.47 36.67 32.74 15.10 10.62 0.32 47.84 49.92

September 2014 0.06 2.01 29.11 36.78 17.81 13.85 0.38 54.59 49.95

October 2014 0.00 1.62 25.57 34.00 18.38 19.73 0.70 52.38 49.96

November 2014 0.00 0.43 16.55 33.03 21.14 27.19 1.66 54.17 50.00

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

requested to kindly adhere to Regulations in this regard.

SRPC Noted the Following:

38 URTDSM (PMU) PROJECT IN SOUTHERN REGION

URTDSM project was planned to be completed within 24 months from the date of

award. A Meeting of the Coordinators of the utilities was held on 19th

September .2014

at SRPC, Bangalore. Installation and Training was likely to commence from December

2014.

39. DRAWAL POINTS OF COASTAL ENERGEN

In the 25th

Meeting of Commercial Sub-Committee held on 22nd

August 2014, it had

been agreed that energy accounting of drawal by Coastal Energen be based on the meters

at Madurai end on Madurai-Coastal line and meters at Coastal end on Coastal-NTPL

line. It had also been noted that energy accounting of startup power drawl by NTPL

would be based on the energy meters provided at NTPL end.


.

40. PAYMENT OF TRANSMISSION CHARGES & OPENING OF LC FOR

DRAWAL OF START UP POWER DURING COMMSSIOING PERIOD BY

GENERATING STATIONS

The matter was further deliberated in the 26th

Meeting of Commercial Sub-Committee

held on 21st November 2014. After deliberations, the following had been agreed:

Generators granted startup power drawal under DSM mechanism would be

advised to open LC in line with the methodology followed by PGCIL in the

GMR Energy Limited case.

As an interim arrangement, transmission charges from the generators

drawing startup power under DSM mechanism could be levied based on the

applicable withdrawal charges by taking approved withdrawal as the

weighted average of MW allocation granted by SRLDC. CTU would collect

the transmission charges based on RTA and RTDA. Disbursement of

amount collected would be carried out after obtaining clarification in this

regard.

41. AUDITING OF ACCOUNT - ANNUAL SUBSCRIPTION FOR CONDUCTING

VARIOUS COMMITTEE MEETINGS OF SRPC

In the 25th

SRPC Meeting, it was noted that the account in respect of annual subscription

for conducting of various Committee Meetings is operated by Chief Engineer, SLDC,

KPTCL. The account was proposed to be audited and the Audit Report submitted to

Chairperson, SRPC. The Committee had approved the above.

Accordingly, the Account had been audited and Audit Report submitted to Chairperson,

SRPC


42. DATE & VENUE OF THE NEXT SRPC MEETING

It was decided to hold the 27th

Meeting of SRPC in due course. Telangana kindly

agreed to host the next Meeting at Hyderabad.

43. VOTE OF THANKS/PLACING ON RECORD CONTRIBUTIONS

43.1 The Committee placed on record the excellent contributions to various forums of SRPC

of Shri R.V.Sundararaman, MD, TANTRASCO, Shri C.Kaliaperumal, Chief Engineer,

TANTRANSCO and also Shri N. Ravi Kumar, Executive Director, SRTS-II, PGCIL

who were due to superannuate shortly.

43.2 MD, TANTRANSCO thanked SRPC for providing necessary guidance and solving a

number of issues.

43.3 Chairperson, SRPC & MD, KPTCL thanked all the Constituents for meaningful

deliberations and arriving at consensus on a number of issues.

43.4 Member Secretary, SRPC thanked Chairperson, SRPC & MD, KPTCL for kindly

chairing the Meeting.

Sd/- Sd/-

(S.R. BHAT) (G. KUMAR NAIK) IAS

Member Secretary, SRPC Chairperson, SRPC & MD, KPTCL

******

Documents

SOUTHERN REGIONAL POWER COMMITTEE - Karnataka · 1.1 The 26thMeeting of Southern Regional Power Committee was held at Visakhapatnam ... Chairman, TANTRANSCO Shri D. Prabhakar Rao,