दविण ित्र विद्यत सववत · In 1971, the first Thermal power plant at Ennore was started with 60 MW capacity. ... reliable and quality power as per

भारत सरकार

GOVERNMENT OF INDIA

विद्युत मंत्रालय

MINISTRY OF POWER

कें द्रीय विद्युत प्राविकरण

CENTRAL ELECTRICITY AUTHORITY

दविण िेत्रीय विदु्यत सवमवत

SOUTHERN REGIONAL POWER COMMITTEE

ददनाकं 25 जुलाई 2014 को चेन्नई मैं सम्पन्न द क्षे वि स के टी सी सी की चौबीसिीीं बठैक के कार्यितृ

MINUTES OF THE 24TH MEETING OF TCC OF SRPC

HELD AT CHENNAI ON 25TH JULY 2014

बेंगलरू

BANGALORE

Minutes of 24th Meeting of TCC of SRPC held on 25th July 2014 Page 1 of 83

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

2. CONFIRMATION OF THE MINUTES OF 23rdMEETING OF TCC .......................................................... 6

3. UTILIZATION OF 220 kV UPPER SILERU-BALIMELA (SR-ER), LOWER SILERU – BARASUR (SR-ER)

& CHIKKODI – KOLHAPUR (SR-WR) LINKS AS INTER-REGIONAL LINKS ............................................ 6

4. FIXING UP LIMIT FOR 400 KV KOLAR-HOSUR D/C LINES ................................................................ 10

5. SYNCHRONISATION OF SR WITH NEWGRID / 765 kV RAICHUR-SHOLAPUR LINE ......................... 13

6. UPCOMING TRANSMISSION SYTEM, TRANSMISSION CONSTRAINTS & LOADGENERATION

BALANCE ........................................................................................................................................ 18

7. AUGMENTATION OF TALCHER- II TRANSMISSION SYSTEM ........................................................... 25

8. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINTVENTURE& UMPP ................................................... 26

9. COAL STOCKPOSITION IN THERMAL STATIONS OF SOUTHERN REGION ....................................... 33

10. LTA QUANTUM IN RESPECT OF UPCL / SCHEDULING OF POWER TO PUNJAB FROM UPCL

(HASSAN – MYSORE 400 KV D/C LINE UNDER SYSTEM STRENGTHENING SCHEME) ..................... 35

11. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR ............................................... 38

12. AVAILABLE TRANSFER CAPABLITY (ATC) /TOTAL TRANSFER CAPABLITY (TTC) .............................. 40

13. IEGC RELATED ISSUES ..................................................................................................................... 45

14. OPERATION OF FILTERS AT HVDC KOLAR ...................................................................................... 58

15. KKNPP RELATED ISSUES ................................................................................................................. 59

16. ALTERNATE / RELIABLE AUXILIARY SUPPLY AT HVDC BHADRAWATHI .......................................... 61

17. PSS TUNING /SYSTEM STUDIES ...................................................................................................... 62

18. IMPLEMENTATION OF ENQUIRYCOMMITTEE RECOMMENDATIONS ............................................ 62

19. REVIEW OF PERFORMANCE OF ULDC SCHEME ............................................................................. 65

20. NON-PAYMENT OF TRANSFORMER CHARGES TO TN BYSOUTHERN REGION CONSTITUENTS

AND PENDING ARREARS PAYMENT BETWEEN BENEFICIARY STATES IN SR .................................. 66

21. OUTSTANDING DUES BETWEEN WR & SR ..................................................................................... 68

22. GRID OPERATION ........................................................................................................................... 69

23. DEMAND VARIATION (Peak Vs Off-peak) ...................................................................................... 71

24. FREQUENCY OF OPERATION OF SOUTHERN GRID ......................................................................... 73

25. TRIPPING DETAILS .......................................................................................................................... 73

26. OPERATION OF TALCHER-KOLAR HVDC TRANSMISSIONSYSTEM IN GROUNDRETURN MODE ..... 74

27. PHYSICAL AND CYBER SECURITY/ CRISISMANAGEMENT PLAN/ BLACKSTART PROCEDURES ....... 75

28. MODIFICATIONS IN OPGW LINKS UNDER FIBRE EXPANSION PROJECT OF SR ............................... 76

29. REPLACEMENT OF PRIMARY MULTIPLEXER EQUIPMENTS INSTALLED UNDER SR-ULDC

PROJECT ......................................................................................................................................... 76


30. DIFFERENCE IN COMPUTATION OF CAPACITY CHARGES OF NTPC STATIONS AS PER NEW

CERC REGULATIONS (2014-19) ...................................................................................................... 76

31. ARBITRARY CURTAILMENT OF STOA AND DENIAL OF URS ............................................................ 77

32. PREPAREDNESS FOR BAD MONSOON............................................................................................ 77

33. UTILIZATION OF EXISTING ROW OF 66KV KUTHUMUNDA – UPPATTY FEEDER .......................... 78

34. PROGRESS OF VARIOUS TRANSMISSION AND GENERATING CAPACITY WORKS ........................... 78

35. START UP POWER DRAWAL BY IL&FS TAMIL NADU POWER COMPANY LIMITED......................... 78

36. UDUMALPET &GAZUWAKA ICTs - STATUS OF CERC PETITION ...................................................... 79

37. SCHEDULING POWER TO TELANGANA & ANDHRA PRADESH FROM SHARED STATIONS, IPPs

AND SIMHADRI STPS STAGE-I ........................................................................................................ 80

38. COLLECTION OF DATA REGARDING POWER SUPPLY TO RURAL AREAS ........................................ 81

39. SNAPPING OF POWER CONDUCTORS OVER TRACTION LINES- SOTHERN RAILWAY ..................... 82

40. TRANSMISSION LINE PATROLLING PROTOCOLS/ GUIDELINES ...................................................... 82

41. DATE & VENUE OF THE NEXT TCC MEETING.................................................................................. 83

42. VOTE OF THANKS ........................................................................................................................... 83


SOUTHERN REGIONAL POWER COMMITTEE

BANGALORE

MINUTES OF THE 24th

MEETING OF TCC OF SRPC HELD AT

CHENNAI ON 25th

JULY 2014

1. INTRODUCTION

1.1 The 24th

Meeting of Technical Coordination Committee of SRPC was held at

Chennai on 25th

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

1.2 Shri C.Kaliaperumal, Chief Engineer/Operation, TANTRANSCO on behalf of

TANTRANSCO, TANGEDCO & TNEB expressed immense pleasure and privilege

in welcoming Shri S.Sumanth, Chairperson TCC, Shri S.R.Bhat, Member Secretary

(I/c), SRPC and other TCC Members to the 24th

Meeting of TCC. He also extended a

Special Welcome to the Members from the newly formed State of Telangana. He

stated that main purpose of grid security was to ensure availability of power supply.

He requested Honorable Members of the TCC to kindly deliberate and evolve

measures to ensure reliable power supply. He pointed out that from the year 1965

onwards; incidents of major grid failure around the world were only around five in

number. There had been no instances of major grid failure in Southern Region. He

requested Managing Director, TANTRANSCO to deliver a few words about the

growth and glorious achievements of TNEB.

1.3 Shri R.V.Sundararaman, Managing Director, TANTRANSCO welcomed all the

delegates to the Meeting. He said that initially there was Composite Madras State

Electricity Department with British Engineer John G. Henry Howard as the Chief

Electrical Engineer. TNEB was constituted in the year 1957 and came to be known

as “Madras State Electricity Board” with Padmashri V.P.Appadurai as Chief

Engineer (Electricity). The first hydro generating station at Pykara (6.65 MW) was

started in 1932 which is still running now. In 1971, the first Thermal power plant at

Ennore was started with 60 MW capacity. First gas station was started in 1992 at

Narimanam. The process of wind power generation started in the year 1986 and 120

wind mill generators with a total capacity of 19 MW were commissioned during the

period 1986-93. In 1992, the power sector was opened to private participation and

GMR Vasavi was the first to establish independent power project. Kadamparai

pumped Storage scheme with an installed capacity of 4x100MW is useful during


peak hour operation. Tamil Nadu is the first state to achieve “all village

electrification” in India. TNEB also stood first in maximum utilization of fly ash in

thermal stations. As on date, the installed capacity of the state was 11,884 MW

serving a consumer base of about 2.52 crore. After a long journey of 53 years, on

01.11.2010 TNEB was restructured into TNEB Ltd., (holding company),

TANGEDCO Ltd. & TANTRANSCO Ltd. Most of the Thermal generating stations

in TN were running at PLF between 80 – 92% even after completion of 25 years

service.

Managing Director, TANTRANSCO proudly announced charging of the 362 KM

long 400 kV Pugalur- Kalavinthapattu line on 23rd

July 2014. This line was part of

the backbone transmission network of Tamil Nadu. 400 KV Kayathar – Karaikudi –

Pugalur line works were nearing completion and would be commissioned shortly.

He added that an all time high peak demand of 13,775 MW had been met on 24th

June 2014 with the help of wind energy with Energy consumption of 294 MU on

20th

June 2014. Recently about 2,500 MW of capacity had been added. Medium term

power purchase agreement up to 2016 for 500 MW and also 15 years long term

power purchase agreement of 3,330 MW had been tied up. A target of 3,000 MW in

3 years for solar energy resources had been planned and was being executed. The

installed capacity of Wind Power in Tamil Nadu as on date was 7,276 MW.

Around 134 sub stations in various places had been commissioned during the

period 2011 to 2013. Around 3,363 circuit KM of EHT lines was charged during

the period 2011 to 2013. The transmission infrastructure in Chennai was being

strengthened at a project cost of Rs. 5,000 Crores with a loan assistance of Rs.3,572

Crores from JICA. Tamil Nadu was going for a long underground cable system in

Chennai city soon. In order to evacuate power from other states, Tiruvalam

substation was under construction and was expected to be ahead of schedule. For the

purpose of evacuation of wind power, 400 kV Substations at Thappagunda,

Anaikadavu and Rasipalayam along with associated lines were under execution.

Schemes at a cost of about Rs.1,593 crores with financial assistance from the

German Government through KFW would be taken up.

Anticipated future growth would be met through addition of about 6,360 MW of

thermal power during the period 2016-2020. Consumers would then be getting

reliable and quality power as per TNEB motto. A copy of the Presentation is


furnished at Annexure- II. The dynamic leadership of Chairman, TNEB in putting

various projects in Tamil Nadu on fast track mode was also placed on record.

1.4 Shri S.R.Bhat, Member Secretary I/c, welcomed Shri S.Sumanth, Chairperson TCC

& Director (Transmission), KPTCL, other Members and Participants to the 24th

Meeting of TCC. On behalf of TCC, he also placed on record the services rendered

by Shri Mohd. Anwaruddin, Director (Grid & Tr. Management), APTRANSCO the

outgoing Chairperson TCC. He thanked Shri R.V.Sundararaman, MD,

TANTRANSCO, Shri C. Kaliaperumal, CE/Operation & Shri Raja Gunanidhi, EE

and other officers from TANTRANSCO/TANGEDCO for the excellent

arrangements made for the Meeting. TANTRANSCO/TANGEDCO had provided

wonderful ambience for conduct of the Meeting and for comfortable stay.

1.5 Shri S.Sumanth, Chairperson TCC & Director (Transmission), KPTCL welcomed

all the Members to the Meeting. He thanked Tamil Nadu Electricity Sector for

hosting the Meeting in a nice atmosphere. He congratulated Shri R.V.Sundararaman

for taking over as Managing Director of TANTRANSCO. He also welcomed the

Directors from the State of Telangana.

1.6 TCC welcomed the following new Members:

Shri S.V.Govindaraju, Chief Engineer (LD), KPTCL

Shri M.G. Suresh Babu, Additional Director (Projects), PCKL

Shri R.V.Sundararaman, Managing Director, TANTRANSCO

Shri Rakesh Samuel, General Manager, NTECL, Vallur STPS

Shri Sunil Agrawal, Director, GMR Energy Trading Ltd.

1.7 TCC also placed on record the excellent services rendered by the following

outgoing Members:

Shri T.Chandrasekhar, Director (Opn), APNPDCL

Shri H.S.Keshavamurthy, Chief Engineer (E), SLDC, KPTCL

Shri S.Akshayakumar, Managing Director I/c, TANTRANSCO

Shri K.Viswanathan, Director ( Opn), TANTRANSCO

Shri Rajendra S.Mirji, Tata Power Trading Company Ltd.

1.8 TCC placed on record the significant contribution of PGCIL in enhancement of the

transmission capacity in Southern Region. PGCIL had recently commissioned a

number of transmission elements (400 kV Nellore – Tiruvalam, 400 kV Thiruvalam

– Kalavinthapattu etc.) under the able leadership of Shri V.Sekhar, ED, SRTS-I &


Shri N.Ravi Kumar, ED, SRTS-II. 765 kV Raichur – Sholapur Circuit under TBCB

had also been recently commissioned with the untiring efforts of PGCIL.

1.9 Member Secretary I/c, SRPC observed that SR was facing around 3,200 MU of

deficit in hydro reservoir storage on account of the inadequate monsoon. TCC

would need to finalize suitable measures to ensure secure grid operation in these

circumstances.

2. CONFIRMATION OF THE MINUTES OF 23rd

MEETING OF TCC

The Minutes of 23rd

Meeting of Technical Coordination Committee of SRPC held

on 14th

March 2014 at Chennai were confirmed.

3. UTILIZATION OF 220 kV UPPER SILERU-BALIMELA (SR-ER), LOWER

SILERU – BARASUR (SR-ER) & CHIKKODI – KOLHAPUR (SR-WR)

LINKS AS INTER-REGIONAL LINKS

3.1 220 kV Upper Sileru-Balimela (SR-ER)

3.1.1 In the 24th

Meeting of SRPC it had been agreed that trial operation of 220kV Upper

Sileru – Balimela line would be carried out for about three months with a caveat

that generation would not be backed down. Line could be operated (switched

on/off) as per requirements of APSLDC.

3.1.2 Subsequently the Operational Procedure had been finalized by SRLDC in

consultation with the stakeholders.

3.1.3 Trial operation of 220 kV Upper Sileru – Balimela line had been carried out on

21stApril 2014 by keeping 2 units of Balimela generating station radially

connected with AP system through split bus arrangement at Balimela. The line

was in service form 1230 hrs.to 1745 hrs. Power flow from Balimela to Upper

Sileru was maintained up to 100 MW. APTRANSCO had expressed concern that

it had taken more than ½ hour for exchanging the code and for Odisha SLDC to

take action. SRLDC had assured for review of the process &stated that they would

suitably take up with NLDC / ERLDC for quicker exchange of codes.

3.1.4 Closing of this line had also been stressed in the Meeting taken by Secretary

(Power) on 6th

May 2014 to discuss preparedness of the power sector to tackle

effects of subnormal monsoon.


3.1.5 AP had placed order for purchase of 150 MW of power on RTC basis from

GRIDCO for the period from 15th

to 30th

June 2014. 220 kV Balimela-Upper

Sileru line was closed from Upper Sileru (AP end) and open at Balimela end.

GRIDCO had not supplied any power to Andhra Pradesh citing shortages due to

unit outages etc.

3.1.6 In the Meeting MS I/c, SRPC informed that a Meeting (through video conference)

with participation of APTRANSCO, TSTRANSCO, OPTCL, GRIDCO, SRPC

Secretariat, ERPC Secretariat, SRLDC, ERLDC and NLDC had been conducted

on 18th

July 2014. It had been decided to initially avail power through UI

mechanism and subsequently scheduled transactions could take place. Approval of

the Govt of Odisha was expected by 28.07.2014.The Minutes of the Meeting is

furnished at Annexure-III.

3.1.7 ED, NLDC said that in view of the deficit in SR and also on account of limited

inter regional corridor availability, operationalization of 220 kV Balimela-Upper

Sileru and Chikkodi – Kolhapur lines had been considered. Efforts were however

on to enhance the inter regional transmission capacity. 220 kV Chikkodi –

Kolhapur line had already been put into operation. Karnataka had started availing

power from Maharashtra in radial mode and about 2 MU of energy was being

drawn on this line daily. Studies had been carried out by SRLDC taking into

consideration the generation level in Sileru complex and line loading. This showed

that about 50 – 100 MW of power could be imported, without causing over

loading of Lower Sileru - Bommur & Upper Sileru - Pendurthi lines. Power could

be availed either on bilateral or on regional basis. However, it appeared that

APTRANSCO had again expressed certain reservations on operationalization of

the line as expressed in their communication dated 24th

July 2014.

3.1.8 Director, APTRANSCO said that during generation in Sileru complex, Lower

Sileru- Bommur & Upper Sileru – Pendurthi lines were getting over loaded.

During the trial operation some units in Sileru Complex were under shut down and

hence overloading of lines had not been experienced. The loading of the Lower

Sileru - Bommur line was around 170 MW. He added that the link could not be

used for import of power in view of generation in Sileru complex and over loading

of lines.


3.1.9 ED, SRLDC suggested that during at least off peak hours power could be imported

on this link. Total generation was around 6-7 MU/day in the Sileru Complex. The

sensitivity was around 26-27 % on Lower Sileru- Bommur line and around 40 %

on Upper Sileru – Pendurthi. There was ample margin available on the Upper

Sileru – Pendurthi line.

3.1.10 MS I/c, SRPC suggested that import of power be avoided during peak hours and

power in the form of UI be availed during other hours. Higher bodies were

monitoring the operationalization of available regional links. Issues regarding

insufficient inter regional corridor availability were being projected by SR. In this

scenario, keeping the link open was rather not justifiable. NLDC had taken

initiative in this regard. After the concurrence from Odisha Government, power

should be imported without affecting any generation in the Sileru complex.

Import of power under UI would also help obtain necessary operational

experience.

3.1.11 TSTRANSCO stated that Sileru is a shared project of AP & Telangana.

Flexibility in operation was an issue and cooperation of both AP & Telangana

was essential to avail power through this link. At times, split bus operation at

Lower Sileru was carried out to ensure power injection towards Telangana and

avoid overloading of Lower Sileru-Bommur line. They further stated that in case

power is availed, it may be on regional basis or to both AP & Telangana.

3.1.12 APTRANSCO suggested further deliberation on this issue in the SRPC meeting.

3.1.13 It was noted that closing of this line had also been discussed in the Meeting taken

by Secretary (Power), especially in view of weak monsoon.

3.1.14 TCC agreed that further decision in this regard could be taken in the SRPC

Meeting.

3.2 220 kV Chikkodi – Mudsinghi / Talandage (Kolhapur) line

3.2.1 In the 24th

Meeting of SRPC after deliberations, it had been agreed that trial

operation of 220 kV Chikkodi – Kolhapur line would be carried out during

June/July 2014, in radial mode. Subsequently, parallel mode of operation could

be contemplated.


3.2.2 In the Special TCC Meeting held on 08th

May 2014, KPTCL had agreed for

closing the Chikkodi – Mudshingi / Talandage (Kolhapur) line.

3.2.3 Meetings to check preparedness for rejuvenation of 200 kV Chikkodi – Kolhapur

line were held at Talandage & Mudshingi on 10th

June and at Chikkodi on 11th

June 2014.Representatives from KPTCL, MSETCL, SRLDC, WRLDC, PGCIL

and SRPC Secretariat attended the Meetings. A Meeting through video

conference with participation from KPTCL, MSTECL, SRPC Secretariat, WRPC

Secretariat, SRLDC, WRLDC and NLDC was also conducted on 17th

June 2014.

The Minutes of the Meeting is furnished at Annexure-IV.

3.2.4 In the Meeting, the following was noted:

This line had been closed radially on 11th

July 2014 and about 70-

100 MW of power was being availed by Karnataka on bilateral basis.

POSOCO suggested that the line be tied in parallel mode.

KPTCL expressed that operation in grid mode was not recommended

at this stage since studies showed that flows may come down.

Further, KPTCL had entered into PPA for 6 months and the voltage

conditions were stable with N -1 criterion.

3.3 RoW of Lower Sileru – Barasur (SR-ER)

3.3.1 In the 24th

Meeting of SRPC after deliberations, it had been agreed to put up a

proposal for utilization of RoW of Lower Sileru - Barasur for higher capacity link

to the Standing Committee on Power System Planning.

3.3.2 Subsequently, Member Secretary I/c, SRPC vide letter dated 11th

April 2014

(Annexure-V) had requested Chief Engineer (SP&PA), CEA to examine

possibility of utilization of RoW of Lower Sileru- Barasur link for a higher

capacity link.

3.3.3 In the Meeting the following was noted:

Matter had been taken up with the Standing Committee on Power

System Planning.

TSTRANSCO opined that upstream and downstream evacuation

system was also needed to be kept in view, while planning the ROW

utilization.


4. FIXING UP LIMIT FOR 400 KV KOLAR-HOSUR D/C LINES

4.1 In the Special Meeting held on 30th

May 2014 with participation of CEA, it had

been agreed that the line loading would be restricted to 580 MW on each circuit of

400 kV Kolar – Hosur D/C line. The flow could be 650 MW on the 400 KV S V

Chatram – Puducherry line.

4.2 TANTRANSCO vide letter dated 3rd

July 2014 (Annexure-VI) had stated power

flow limit on 400 kV Kolar-Hosur D/C line had been fixed at 1,160 MW. This was

not a satisfactory level of operation since assets have been underutilized. It had

also been stated that TN had not been allowed to over draw through UI citing

overloading of 400 kV Kolar-Hosur D/C lines. However, KSEB had been allowed

to over draw about 1,569 MU for the above said period through the same feeders

only. Further, no SPS for overloading of 400 kV Hosur-Salem D/C line had been

provided by KSEB whereas it had been insisted only on Tamil Nadu. It had also

been stated that only STOA had to be curtailed in real time operation to restrict line

loading. Further, priority for reducing STOA/MTOA should be adopted for line

loading before asking for generation reduction in TN. Additional lines planned

between S1-S2 should also be expedited to limit overloading of 400 kV Kolar-

Hosur line. It had also been stated that it could be deliberated whether allowing

1,500 MW power flow through the above Twin Moose conductor would endanger

the lines.

4.3 In the Meeting, MD I/c, TANTRANSCO said that the power flow on this line had

been fixed as 1,160 MW resulting in under utilization of the asset. Maximum limit

of power flow could be raised to 1,500 MW though the thermal limit was about

2,058 MW for both the lines (twin moose conductors) as given in the CEA

Transmission Planning Criteria. Tamil Nadu had been deprived drawal of its

rightful share from the grid where as KSEB has been allowed utilizing the line.

4.4 CE(O), TANTRANSCO observed that 400 KV Kolar- Hosur being a short line

could be easily loaded up to thermal limits. He added that Kerala had over drawn

about 1,569 MU through the same corridor while Tamil Nadu had under drawn 438

MU [2012-13, 2013-14 & 2014-15 (up to May)]. TN had thus been deprived of its

share. This had caused a loss of about Rs 109 crores to TN. Moreover, Kadamparai

pump mode had been asked to stop even during under drawl in high frequency


conditions. TN had tied up about 3030 MW of LTA and in case the present limit of

S1 – S 2 corridor is maintained, then it would be a big struggle to draw the power.

4.5 MS I/c, SRPC pointed out the quality of overdrawal / underdrawal also mattered.

Overall figures may not capture the dynamics involved in real time grid operation.

Under drawl could also be on account of any infirm power injection. Over

drawal/Under drawal was being regulated as per the limits specified in DSM/UI

regulations of CERC. Deviations, if any, were supposed to be only unintended.

SRLDC was monitoring the drawals etc in an impartial manner and accordingly

issuing violation messages.

4.6 Director (Tr. & SO), KSEB stated that though there would have been over drawal

of about 1,570 MU, they were adhering to the Regulations. KSEB was also

complying with any direction of SRLDC in maintaining Grid discipline. Violation

messages were being issued by SRLDC in real time to all such constituents

including KSEB in the event of any non-compliance of the Grid code.

4.7 ED, SRLDC pointed out that instantaneous OD/UD was of much greater

significance with regard to Grid Operation. Whole year OD/UD comparison in

terms of MU would not give the correct perception in this regard. 580 MW limit of

power flow on each circuit had been fixed keeping in view N-1 contingency as per

the Planning Criteria of CEA.

4.8 Chief Engineer (O), TANTRANSCO stated that each line (short) could carry 750

MW as per the thermal limits in the Planning Criteria of CEA. Further,

commitment given earlier regarding increase of ATC of S1-S2 corridor had not

been implemented even though SPS on 400 KV Hosur-Salem had been

implemented and was in place.

4.9 MS I/c, SRPC suggested that the SPS at Salem be shifted to Hosur since Hosur

loads were having higher sensitivity with respect to flow on Kolar-Hosur lines.

Additional relief of about 125 to 150% could be provided so as to ensure that N-1

criterion does not get violated. In case regulatory requirements were satisfied (CEA

Planning Criteria/Congestion Regulation) enhancement of S1-S2 ATC could be

considered by NLDC/SRLDC.


4.10 ED, SRLDC said that N-1 condition needed to be satisfied at all times.

Effectiveness of SPS was also under scrutiny considering past experience. Hence,

ATC enhancement could not be considered with SPS.

4.11 ED, NLDC said that limit of 1,160 MW (thermal limit) was fully in accordance

with provisions of CEA’s Planning Criteria with N-1 contingency. The conductor

was ACSR twin moose conductor. In certain critical corridors, even N-1-1

contingency was being considered. During the past couple of months, North

Chennai Units had tripped more than 75 times resulting in sudden fluctuations in

power flow. At times, N-1 criteria had been violated for Kolar-Hosur lines for

about 70% of the time. Without considering SPS, N-1 contingency was to be

satisfied as per provisions of the Planning Criteria.

4.12 MS I/c, SRPC suggested that ambient temperature/dynamic rating/SPS could be

contemplated for improvement in utilization of transmission assets. In view of the

weak monsoon this year, enhancement could be considered as a special case.

4.13 ED, SRTS-I, PGCIL informed that the 400 kV Kolar-Hosur lines were each

carrying about 650-700 MW of power on a sustained basis for the past two years.

At times, hotspots had been observed. He stated that the line had to exist to

evacuate power and hence sustained over loading may not be recommended.

Though the line could carry power up to thermal limits, the system operator should

feel comfortable.

4.14 Director (Tr.& SO) KSEB stated that lines were designed for loading up to thermal

limits. KSEB was willing to participate in any SPS, in case S1-S2 corridor

enhancement was being considered.

4.15 MD, TANTRANSCO assured effectiveness of the contemplated SPS and requested

NLDC/SRLDC to consider enhancement of ATC. He added that enhancement was

only being requested in the interim period till such time other

evacuation/strengthening schemes are completed.

4.16 Director (Tr), KPTCL suggested that PGCIL may kindly revert back with technical

details and feasibility, if any, of utilization of this link at higher limits with SPS


4.17 Summary of deliberations in the Meeting is as follows:

It was suggested that SPS at Hosur for the 400 KV Kolar- Hosur lines

be considered. 125-150% of loads could be ensured. KSEB would also

participate in SPS.

With provision of SPS, NLDC/SRLDC could consider enhancement of

S1-S2 ATC to some extent.

SPS at Salem for 400 KV Hosur – Salem lines could be dismantled.

PGCIL informed that they would revert back with feasibility in this

regard.

5. SYNCHRONISATION OF SR WITH NEWGRID / 765 kV RAICHUR-

SHOLAPUR LINE

5.1 In the 24th

Meeting of SRPC, the following had been noted:

765 kV Raichur –Sholapur S/c line (executed by PGCIL) was synchronized

on 31st December 2013. SRPC had approved the CoD of 765 KV Raichur –

Sholapur S/c line and Raichur 765/400 KV S/S from 1stJanuary 2014.

POSOCO had stated that commissioning of 765 KV Raichur-Sholapur line

was one necessary step towards integrated National Grid. Frequency

fluctuations had come down with the synchronization of SR grid and NEW

grid. The line was carrying up to 900 MW of power in either direction

every day. The issue of oscillations would get resolved with the

commissioning of the other circuit. After commissioning of the

downstream and upstream planned system (18 elements), scheduled

transactions up to 1,200 MW may be allowed. However, other corridors

between NEW Grid and SR Grid were also essential.

TANTRANSCO had stated that long term open access had been granted

for availing power from Chhattisgarh, Orissa & Maharashtra. The

complete system should be in place to ensure transfer of power. Progress of

the 18 identified elements was thus highly critical for the region.

APTRANSCO had suggested proactive action and closer coordination with

the district administration for early resolution of the RoW issues.

PGCIL had stated that despite taking up the issue in Courts and also at

various levels of Administration/Govt. of Karnataka, RoW issues at

Yelahanka and Madhugiri had not yet been resolved. Yelahanka was a GIS

station and could be dismantled and relocated. KPTCL had informed that

about Rs. 9 Crores had been deposited by PGCIL as per directions of the

Court. With additional compensation of about Rs. 1-2 Crores, the issue

could get resolved. KPTCL had invited PGCIL for a Meeting to sort out the

issues in this regard.

KPTCL had stated that PGCIL should not dismantle Yelahanka station and

instead sort out the RoW issues. This was not a stray case as could be seen


in the case of other lines such as Edamon-Kochi etc. KPTCL was taking up

the issues seriously and would facilitate a Meeting at the earliest.

5.1.1 The second circuit of 765 kV Sholapur – Raichur line of M/s RSTCL was

synchronized at 1456 hours of 30th

June 2014.

5.1.2 TANTRANSCO vide letter dated 3rd

July 2014 (refer Annexure-VI) had stated

that it had been agreed that a quantum of power of about 2,000 MW could be

imported to SR region after commissioning of 2 Nos. 765 kV lines along with

other transmission elements in WR and SR regions. The status of line had been

proposed to be deliberated in the Meeting.

5.1.3 In the Meeting, MS I/c, SRPC informed about the petition of MSETCL before

Hon’ble CERC for keeping in abeyance the ongoing trial operation of NEW-SR

synchronization till satisfactory resolution of all their concerns arising out of the

trial run. A Meeting on TTC/ATC/LTA issues related to Raichur-Sholapur link

had been conducted on 24th

July 2014 in New Delhi and the outcome was

awaited.

5.1.4 CTU informed that based on the feedback of KPTCL on load generation balance

issues etc. no conclusion could be arrived at. Hence another Meeting in this

regard had been scheduled to be conducted on 30th

July 2014.

5.1.5 Director (Tr), KPTCL also noted that there had been no decision taken regarding

increase of TTC/Allocation of corridor for LTA during the Meeting held on 24th

July 2014. As per their observation there was no need to unnecessarily hurry and

avail more power through existing link. Number of downstream/upstream

lines/system were in various stages of commissioning. Hence, it was needed to be

technically ascertained whether the present system was capable of handling this

additional power. He added that within a period of about 6 months, the Grid

would be strengthened with commissioning of other elements and then additional

power could be availed. It was appreciated that POWERGRID was doing its very

best in early/timely commissioning of the elements.

5.1.6 MD, TANTRANSCO stated that more flexibility was required in allocation of

corridor to ensure higher availability of power to Tamil Nadu. Step by step

enhancement of ATC needed to be considered, with progressive commissioning

of new elements. Hence, waiting for the entire system to be completed before


release of ATC may not be the right approach.

5.1.7 ED, SRLDC informed that 200 MW of STOA was being scheduled from 05th

July

2014. Prior to commissioning of the second circuit, flow was within 800 MW

import/export on net nil basis.

5.1.8 Director (Tr. & SO), KSEB observed that since certain downstream lines had

already been commissioned, the study was suggesting additional import. One

could not wait for the whole system to come up to release ATC. The ATC could

be released to the extent possible with the available elements, based on studies.

5.1.9 Chief Engineer (O), TANTRANSCO added that Nellore-Thiruvalam line was

lightly loaded and more power flow could be availed with the commissioning of

other downstream transmission system. He also informed that Thiruvalam-

Melakottiyur and Mellakottiyur-Pugalur lines had been commissioned.

Thiruvalam downstream system was also likely to be commissioned within a

month.

5.1.10 ED, NLDC said that review of available downstream system and commissioning

schedule may also be undertaken in the Meeting scheduled on 30th

July 2014 so as

to take a comprehensive view on the TTC/ATC.

5.1.11 Director (Tr) KPTCL observed that with the commissioning of first Raichur-

Sholapur circuit, there had not been any additional net import to the Southern

Region. Power flow on HVDC links had been modulated so as to accommodate

flow on the Raichur-Sholapur link.

5.1.12 The Schedule of commissioning of the planned (18 Nos.) transmission elements

in WR and SR noted in the Meeting is as follows:

Sl.

No. Name of Transmission Element

Exe.

Agency

Date as

noted in

CEA Mtg.

held on

09.09.2013

Expected

date Remarks

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 September

2014

Forest clearance

St-I received in

Jan 14 and St-II

received in Apr.

14.


4. Raipur 765/400 kV S/S PGCIL Dec. 2013 Completed

5. Wardha-Aurangabad 765kV D/C PGCIL July 2014 Completed

6. Aurangabad 765/400 kV S/S PGCIL July 2014 Completed

7. Sholapur-Pune 765 kV S/C PGCIL Oct.2014 Oct-2014

8. Pune 765/400 kV S/S PGCIL Oct. 2014 Oct./Nov

2014

9. Gooty-Madhugiri 400 kV D/C PGCIL June 2014 Nov/Dec

2014

Severe RoW

Problem near

Madhugiri

10. Madhugiri 400/220 kV S/S PGCIL June 2014 Nov 2014 Engg., supply,

civil works &

erection under

progress

11. Madhugiri-Yelahanka 400 kV D/C line PGCIL June 2014 Mar 2015 Severe Row

Problem

12. Raichur-Kurnool 765 kV S/C PGCIL Aug-2014 Commissioned

13. Kurnool 765/400 kV S/S PGCIL Aug-2014 Commissioned

14. Kurnool-Thiruvalam 765 kV D/C PGCIL Nov.2014 Nov. 2014

15. Thiruvalam 765/400 kV S/S PGCIL Nov 2014 765 kV by

Nov 2014

400 kV

Commissioned

16. Vijayawada-Nellore 400 kV D/C PGCIL Nov. 2014 Nov. 2014 RoW Problem.

17. Nellore-Thiruvalam 400 kV D/C PGCIL Nov.2014 Commissioned

on 14.04.2014

18. Thiruvalam-Melakottaiyur 400 kV

D/C

PGCIL Nov.2014 July 2014 Commissioned

on 24.07.2014

5.2 Review of SPS operation in respect of 765 kV Raichur-Sholapur line

5.2.1 In the Meetings of OCC, constituents had expressed concern over

frequent/spurious SPS signal generation. The SPS which had acted (flow

threshold violation, dp/dt, SPS due to line imp.) and its source (i.e.

Sholapur/Raichur, Wardha & Parli) were not discernible. The source and type of

signal initiation was needed to be ensured to SRLDC/Constituents. There were

instances ‘Nil’ relief by some of the constituents in certain instances.

5.2.2 Based on the operational experience of the All India grid with 765 kV Raichur –

Sholapur I in operation, NLDC vide letter dated 11th

April 2014 had proposed to

revise the SPS settings of some of the schemes. The objective was to minimize

the load or generation loss for normal events while ensuring reliability of All

India Grid. The proposed revisions/modifications suggested by NLDC were

discussed and approved in the 31stMeeting of PCSC. It had been noted that SPS in

SR had been implemented while some SPS implementation/modifications in other

regions were pending. Subsequently NLDC vide letter dated 27th

June 2014 had

intimated that some of the SPS settings had been revised online in Western


Region side. The SPS settings have been revised in Southern Region side after

availing shutdown of 765 kV line on 25th

June 2014.



that additional SPS implemented from end January 2014 has caused many number

of spurious trippings thereby causing load interruptions. It has also been stated

that the status of withdrawal of above SPS has to be deliberated. Further, in the

context of commissioning of second circuit of 765 kV Raichur-Sholapur line,

actual requirement of SPS be deliberated.

5.2.4 NLDC vide letter dated 07th

July 2014 had suggested modifications in the SPS

settings consequent to commissioning of second circuit of 765 kV Sholapur –

Raichur line of M/s RSTCL and also 765 kV Wardha – Aurangabad D/C line.

5.2.5 In the Meeting, MS I/c, SRPC informed that NLDC had reviewed the settings

based on operational experience & also commissioning of the second Raichur –

Sholapur circuit. It had therefore recommended increasing the threshold limit to

1,500 MW (2.5 sec delay). He informed that SPS had operated during instances of

unit trippings, load changeovers, LGB changes in either regions etc. Lack of

adequate RGMO response on either sides was also getting reflected in sudden

variations of power flow on the link. The analysis of SPS operation is furnished at

Annexure-VII

5.2.6 ED, SRLDC said that in certain instances, the SPS signal had not been

communicated on account of non-redundancy of transmission channel. Hence,

load shedding in SR which was warranted operationally as per desired logic had

not taken place. Issue regarding provision of additional channel was being

continuously pursued with PGCIL.

5.2.7 ED, SR-1 said that provision of redundant channel would be ensured. PGCIL

also informed that revised settings as suggested by NLDC would be implemented

on 30th

July 2014.

5.2.8 NLDC informed that modification had to be carried out at both WR/SR ends.

They also suggested that the modifications be carried out on one circuit at a time.

5.2.9 CE (O), TANTRANSCO said that it had been informed earlier that the SPS

would be withdrawn after commissioning of the second circuit.

5.2.10 It was noted that SPS logic was undergoing changes based on operational

experience etc. and also with progressive commissioning of


downstream/upstream elements. The number of SPS operations of late had also

come down as could be kindly seen from the analysis above. Review of SPS

logic was an ongoing exercise.

5.3 Synchronizing facility at Raichur end of 765 kV Raichur – Sholapur line

5.3.1 In the OCC Meetings, SRLDC had stated that synchronizing facility was

required at Raichur end of 765 kV Raichur – Sholapur line to avoid delay in

restoration of vital inter-regional link. Separate synchronizing facility needed to

be provided for both the lines by PGCIL at both ends. PGCIL had informed that

the process for provision of synchronizing facility had already been initiated and

taken-up with the manufacturer.

5.3.2 In the Meeting, PGCIL informed that synchronizing facility had been provided

for both the circuits at both the ends.

6. UPCOMING TRANSMISSION SYTEM, TRANSMISSION CONSTRAINTS

& LOADGENERATION BALANCE

6.1 In the 24th

Meeting of SRPC, APNPDCL had stated that in respect of PGCIL

lines, the stage at which forest clearance was pending should be made known

clearly, clearances could be pending either at state headquarters or with Central

Empowered Committee etc. This information was essential in estimating whether

the projected commissioning dates were reasonable or not. There could be

instances of shifting bottlenecks also which need to be recognized and prevented.

TANTRANSCO had stated that power supply position and constraints including

state wise plans for the next 5 years should also be presented.

6.2 Accordingly, in consultation with the constituents, upcoming Load Generation

Balance for SR (upto 2019-20), upcoming ISTS including Inter-Regional, Intra-

STS& constraints in transmission requiring immediate attention were prepared

and circulated for comments. The following are the issues in this regard:

Regarding anticipated LGBR, feedback has been received from some

of the constituents. Other constituents had been kindly requested to

furnish feedback with regard to Requirement & Availability after

discussions with the concerned DISCOMs/GENCOs/IPPs. The

objective is to compile a realistic LGBR. Unlike Transmission, there is

no centralized agency which could furnish inputs on power purchases

computed on assessment based on actual progress of the Generating

Stations etc. Similarly, the information with regard to ISTS connected

generators is also not readily available.


Regarding transmission, constituents had been requested to

communicate the updated progress and timely information. Any

dropped project needs to be removed from the Progress Reports.

Modified schemes also need to be taken care appropriately. Status of

Forest clearance is awaited from all the constituents. Status of RoW

issues also needs to be elaborated.

6.3 In the 24th

Meeting of SRPC the following had also been noted:

SRLDC had pointed out that status of down stream elements from

substations such as Madhugiri, Yelahanka and Thiruvalam S/S was

also needed to be discussed. Monitoring of status of transmission lines

planned by State Utilities and also lines coming under TBCB route

was required to be carried out. Periodic reports from STUs be sought

in this regard.

APTRANSCO had suggested certain modification with respect to the

scheme for evacuation of Hinduja power as discussed in the 36th

Standing Committee Meeting. TCC suggested that any proposal in this

regard was needed to be addressed to the Standing Committee on

Power System Planning.

In view of commissioning of Krishnapattanam JV, APGENCO had

requested that downstream Thiruvalam system of TANTRANSCO be

in place at the earliest. TANTRANSCO had informed that the

construction of these critical elements had been awarded to major

companies like L&T/Gammon to ensure that projects are completed as

per schedule. Incentive for early commissioning was also being

offered. Thiruvalam S/S was being planned to be completed by June

2014. Thiruvalam-Mettur and Almathy-Thiruvalam lines were also

progressing on fast track.

KPTCL had opined that need for the proposed 400 KV UPCL-

Kasargode-Kozhikode line required to be relooked. This may be a case

of over design. 400 kV Mysore-Kozhikode line (quad moose D/C) was

expected to be operational in about six months’ time. 400 kV Mysore-

Kozhikode line with capacity of about 1,600 MW could amply serve

the requirements of North Kerala. The peak demand of Kerala

presently was of the order of 3,300 MW. The need for UPCL-

Kasargode-Kozhikode line was thus to be examined in the scenario of

400 KV Edamon-Kochi and Trichur - Kozhikode lines coming up.

KSEB had stated the UPCL-Kasargode-Kozhikode line had been

approved by Standing Committee on Power System Planning. All the

aspects had been duly considered and deliberated before according

approval for the line. There was need to strengthen supply to North

Kerala. Kerala had several constraints as far as internal generation was

concerned. It was thus forced to get power from other states. It had

been recommended that CEA be kindly requested to form a

Committee to explore space for additional Bays at UPCL.

Chairperson, SRPC had opined that in view of serious RoW issues,

long term requirements needed to be considered especially in respect

of tower design. Re-conductoring could always be carried out, but


there was a case for appropriate tower design. Towers may need to be

initially designed keeping in view the anticipated growth over the next

30 to 40 years.

6.4 Subsequently, Member Secretary I/c, SRPC vide letter dated 11th

April 2014 had

requested Chief Engineer (SP&PA), CEA that a visit of CEA officers to UPCL

plant be arranged to explore the possibility of space for the additional bays.

6.5 SRLDC had informed about that transmission constraints being faced by system

operators were being communicated to CEA, CTU and states regularly. The

quarterly operational feedback on transmission feedback is available on the

NLDC web site.



that STOA is being curtailed on daily basis even though SPS on 400 kV Hosur-

Salem line has been provided only by TN for which the ATC had not been

increased. It had also stated that the to relieve S1-S2 corridor congestion, erection

works of 400 kV D/C lines (Somanahalli - Salem, Mysore - Kozhikode, Edamon

– Cochin, Trichur – Kozhikode) be expedited by POWERGRID. Further,

Karnataka had to cater their Yerandahalli load of about 80 MW from Somanahalli

itself.

6.7 ED, SRTS-I, PGCIL informed that a number of elements had been progressively

commissioned like Gooty-Nellore-Thiruvalam, Raichur-Kurnool, Chittor-

Thiruvalam, Kurnool (new)-Kurnool (AP), LILO of Nagarjuna Sagar-Gooty at

Kurnool, LILO of Kolar- Sriperumbudur at Thiruvalam. Kurnool-Thiruvalam and

Gooty-Madhugiri were critical pending elements. Out of 214 KM of Gooty-

Madhugiri 70 KM was in Karnataka and they were facing RoW issues in a few

locations. Government of Karnataka was extending support to resolve RoW issues

at Madhugiri and similar co-operation was required to address RoW issues at

Yelahanka. In case conditions are favorable, Gooty-Madhugiri and Madhugiri 400

kV S/S would come up by Nov-Dec 2014. In case RoW issues of Madhugiri-

Yelahanka link are addressed they were hopeful to complete the system by March

2015. He requested the states to complete their downstream system also matching

the schedule of POWERGRID at Madhugiri, Yelahanka etc. to ensure better

utilization of the assets.


6.8 Director (Tr), KPTCL informed that Madhugiri downstream connectivity/loading

had been initiated. Bellary-Madhugiri line was also being undertaken. Yelahanka

(PG) – Yelahanka (KPTCL) connectivity was being planned through UG cable

considering the RoW issues in that area.

6.9 In the Meeting, the progress of the following critical elements had been noted:

S.

No.

Transmission Element Schedule Remarks

1 400 kV Chittoor-Thiruvalam March 2014 Commissioned in March 2014

2 765 kV Salem- Madhugiri March 2015 Severe RoW problem near

Madhugiri

3 765 kV Narendra (Kudgi)-Kolhapur Nov. 2015 Tower Packages awarded (Part-

II) in Nov. 13. Completion

matching with Kudigi SS. Land

acquired in Feb. 2014

4 765 kV Madhugiri-Narendra (Kudgi) Nov. 2015 TBCB

5 400kV Krishnapattanam- Chittoor Oct. 2014 APTRANSCO was requested to

expedite commissioning to

avoid evacuation constraints

6 400/230 kV Thiruvalam S/S ICT-1 by

15.08.2014

ICT-2 by

31.08.2014

LILO of 230 kV D/C line

proposed. Expected load would

be around 200- 300 MW.

7 400 kV Thiruvalam - Melakottaiyur Commissioned on 24.07.2014

8 400 kV Somanahalli- New Salem Dec. 2014 Shut down in September 2014

COD by December 2014

9 400 kV Pugalur- Kalavindapattu Sep. 2014 One Ckt commissioned. 2nd

Ckt

by Sep 2014

10 400 kV Mettur- Singarapet-

Thiruvalam

Sep. 2014 40% of total work completed.

11 LILO of Kolar- Sriperumbudur at

Thiruvalam

Commissioned in March 2014

12 400 kV Mangalore (UPCL ) -

Kasargode-Kozhikode

Approved by Standing

Committee.

6.10 Director (Transmission), KPTCL stated that the issue regarding 400 kV UPCL –

Kasargode – Kozhikode line be discussed in the ensuing Standing Committee. It

was felt that this link may serve no purpose and it would be a wasteful investment

considering the Mysore-Kozhikode line which would be commissioned shortly.

6.11 Director (Tr. & SO), KSEB stated the 400 KV UPCL- Kasargode-Kozhikode line

had been approved by Standing Committee on Power System Planning. He added

that approved issues should not be reopened.


6.12 PGCIL informed that the proposed 400 kV Mangalore (UPCL)-Kasargode-

Kozhikode line would be through TBCB route.

6.13 MD, TANTRANSCO requested to consider one more ICT at Kalavinthapattu.

PGCIL informed that NIT had been issued and they would expedite to the extent

possible.

6.14 PGCIL informed that shutdown for 45 days of 400 kV Somanahalli-Hosur line for

construction of Somanahalli-New Salem line approved in the 24th

SRPC held on

15th

March 2014 had not been taken up and would be availed in September 2014.

6.15 MD, TANTRANSCO observed that there would be considerable wind generation

reduction from October onwards and PGCIL should make all efforts to avail the

shutdown before September 2014. Shutdown proposal after September may not

be approved keeping in view the operational reasons.

6.16 MS I/c , SRPC informed that the 37th

Meeting of Standing Committee on Power

System Planning was scheduled on 31st of July 2014 wherein the issues could be

deliberated. About 10,000-16,000 MW deficit was anticipated in Southern Region

in 2019-20 as per the agenda circulated. He stated that a Special meeting of TCC

be held to approve the schemes recommended in the 37th

SCPSP SR

.Transmission constraints etc. could be discussed in that Meeting.

6.17 ED, SRLDC stated that unless the 765 kV Narendra (Kudgi)-Kolhapur line was

ready, evacuation of Kudgi generation would not be possible.

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

6.18.1 In the 24th

Meeting of SRPC the following had been noted:

PGCIL had informed that they were receiving assistance from the

Karnataka Administration. Considerable agitation was being

encountered, but works were taken up with police protection. If

conducive environment was maintained, the line could be completed

by January 2015.

KSEB had observed that the line needed to be completed at the

earliest and had requested KPTCL to kindly render all support to

PGCIL.

6.18.2 It was learnt that Karnataka State Government had constituted an Expert

Committee to examine alternative possibilities for the line.


6.18.3 KSEB vide letter dated 14th

July 2014 (Annexure-VIII) had been stated that

the completion of 400 kV Mysore-Kozhikode (Areakode) D/C line is urgently

required as Northern Kerala was facing acute power shortage. Due to forest

clearance and RoW disputes, the line work is held up in Karnataka. The 400

kV line work in Kerala and the construction of 400 kV substation at Areakode

were completed and kept idle for want of this line.

6.18.4 In the Meeting, Director (Transmission), KPTCL informed that the 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.

6.19 Edamon-Cochin 400 kV line

6.19.1 KSEB had stated that completion of this line was essential for increasing the

import capability of Kerala and also for efficient evacuation. Construction of

this line had been held up on account of severe RoW issues.

6.19.2 In the previous SRPC Meetings, the following had been noted:

PGCIL had stated that additional compensation of about Rs.330-

350 Crores was not viable. The matter had been discussed a

number of times with the State Government. Payment of

additional compensation would send wrong signals to various

other projects of PGCIL in the country. The material was lying

unutilized since there was no progress since past 5-6 years. There

had been no progress after the High Level meeting in December

2013.Hon’ble Chief Minister of Kerala had already taken a

couple of Meetings in this connection. They had approached

Court for getting suitable directions to complete the work. The

Court had not passed any orders. PGCIL was also willing to

handover this project to KSEB. PGCIL Board had considered

dismantling of the asset on account of severe RoW problem. It

was stated that they may subsequently approach Hon’ble CERC

for relief since they wanted to minimize losses. Since the project

was much delayed, IDC may also not be approved by

Commission.

KSEB had stated that out of Rs 1,800 Crores scheme cost,

PGCIL had already invested about Rs 1,400 Crores and the

project could not be abandoned at this stage. KSEB had also

surrendered RoW for a section of this line. KSEB also assured

further coordination to sort out this issue. Discussions and efforts

to resolve the issue were under way. During the last one year,

Hon’ble Chief Minister had convened three Meetings on this


issue. There were court orders with regard to compensation. In

Kerala, about 30- 40% compensation was payable for the

corridor and 100 % for the tower foot print.

Chairperson, SRPC had suggested that the issue be mutually

discussed between KSEB and PGCIL, once the election process

was over.

6.19.3 POWERGRID had filed a petition before Hon’ble CERC seeking provisional

tariff on the expenditure incurred by PGCIL on construction of Edamon -

Cochin 400 kV D/C (Quad) line till 31.3.2014 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 is stated:

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

complete the Projects and seeks recovery of expenditure already

incurred in a suitablemanner. “

The Petition had been listed for hearing on 12th

August 2014.

6.19.4 In the Meeting, Director (Tr. & SO), KSEB informed that additional

compensation would be met by the Government of Kerala. Therefore there was

likelihood of commissioning of this line which would stabilize power supply to

central Kerala. He requested PGCIL to complete this project at the earliest.

6.20 400 kV Trichur-Kozhikode line (Madakkathara-Areakode)

The following had been noted till 24th

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. In the 14th

SRPC Meeting,

KSEB had denied the possibility of surrendering the RoW of the

KSEB line since energy security of Malabar region was involved.

Line 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.


7. AUGMENTATION OF TALCHER- II TRANSMISSION SYSTEM

7.1 The following had been noted till 24th

Meeting of SRPC:

Government of India order was required in case PGCIL was to

implement this scheme under “urgency” clause.

TANTRANSCO vide letter dated 5th

January 2013 had stated that all

SR beneficiaries had entered into Transmission Service Agreement

with M/s. TTCL regarding the strengthening of Talcher-II evacuation

system. As per TSA & LOI, M/s. TTCL had to achieve the CoD by

31.03.2013 and submitted bank guarantees were valid up to end of

Jan 2013 with a claim period of one more month. Presently, M/s.

TTCL had approached Hon’ble CERC praying relief in the matter of

extension of time and other issues vide Petition No.

170/MP/2011.Hence, M/s. TTCL had to be instructed to complete the

scheme at the earliest.

Chairperson, SRPC vide letter dated 14th

March 2013 addressed to

Secretary (Power), MoP had invited attention to the matter regarding

delay in execution of augmentation of Talcher-II transmission

system. It had also been requested that MoP may consider issuing

suitable directions to Hon’ble CERC since public interest was also

involved.

In RoP dated 9th

July 2013 Hon’ble CERC had directed NKTCL and

TTCL to hold a Meeting with the Procurers of both projects within a

period of two weeks and file the outcome of the meeting before 30th

July, 2013. The Commission had further directed the lead procurers

of NKTCL, namely MSEDCL and TANGEDCO to coordinate the

LTTCs to facilitate the meeting with NKTCL and TTCL.

In the RoP dated 8th

August 2013, Hon’ble CERC had directed CEA

to submit the present status of the NKTCL & TTCL latest by 30th

August 2013. In the RoP dated 10th

September 2013, it is stated that

CEA vide letter dated 29th

August 2013 had confirmed that no

progress had been made for implementation of the project.

Commission had directed PSPCL to file its reply and submissions

made during the hearing on affidavit, with an advance copy to the

petitioner and NKTCL and TTCL by 20th

September 2013. NKTCL

& TTCL were to file their rejoinders, if any, on or before 27th

September 2013. The Commission had reserved order in the

Petitions.

TANTRANSCO vide letter dated 8th

January 2014 had referred to the

judgment of Hon’ble Appellate Tribunal for Electricity in respect of

Appeal No.140/2013 preferred by Talcher-II Transmission Co.Ltd. It

had been stated that TANTRANSCO was of the view to go for appeal

before Hon’ble Supreme Court. Standing Counsel had been requested

to file the appeal before Hon’ble Supreme Court, on behalf of

TANTRANSCO, on account of the urgency involved.


TANTRANSCO had informed that after issuance of Orders by

Appellate Tribunal of Electricity, Talcher–II Transmission Company

Ltd. had sought enhancement of transmission charges by about 86%

to compensate increase in cost/expenses. TANTRANSCO had

approached Hon’ble Supreme Court. TANTRANSCO also suggested

that requirement of line (Talcher-Gazuwaka) be reviewed in the

present grid scenario, since other lines were coming up.

SRLDC had stated that all studies were being carried out with

assumed availability of the Talcher backup system, which was also

required to ease congestion. He informed that in the absence on-

availability of adequate transmission corridor, STOA via ER was

being curtailed.

It had been suggested that requirement of Talcher backup system be

taken up with Standing Committee on Power System Planning,

considering the system planned/under execution.

7.2 Subsequently, TANTRANSCO vide letter dated 05th

April 2014 had informed that

they had filed a Civil Appeal before the Hon’ble Supreme Court on 03rd

March 2014.

7.3 The matter had accordingly been taken up with CEA vide SRPC letter dated 24th

April

2014 (Annexure-IX).

7.4 In the Meeting, it was noted that the matter was sub-judice, since an Appeal had been

filed before Hon’ble Supreme Court.

8. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINTVENTURE& UMPP

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

8.1.1 In the 24th


Hon’ble CERC vide Order dated 08.01.2014 in Petition No.

190/TT/2013 for adoption of Tariff (Transmission Charges) in respect

of the following Transmission System being established by Kudigi

Transmission Limited under Tariff Based Competitive Bidding

process, had approved levelised transmission charges:

Kudigi TPS- Narendra (New) 400 kV 2xD/C quad lines

Narendra (New)–Madhugiri 765 kV D/C line

Madhugiri–Bidadi 400 kV D/C (quad) line

NTPC had informed that synchronization of Unit-I was expected

during September 2015 and Unit-II during March 2016.

KPTCL had informed that huge 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.


8.1.2 In the Meeting, NTPC informed that progress would be informed in the SRPC

meeting by Regional ED.

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

8.2.1 In the 24th


NLC had informed that CoD of Unit-I would be by 31stMarch 2014

while CoD of Unit-II was expected by May 2014.

NLC had also informed that the Petition before Hon’ble CERC for

maintaining status-quo in injection of infirm power under UI

mechanism till declaration of CoD or 31stMarch 2014 had been

heard and Order was awaited. NLC had been requested to obtain

orders from Hon’ble CERC immediately.

8.2.2 Subsequently, Hon’ble CERC vide Order dated 20th

May 2014 had granted

extension of time for injection of infirm power from the generating station for a

further period upto 30th

June 2014. In the Order, it had also been mentioned that

any prayer by the Petitioner for further extension of time beyond 30th

June 2014

shall not be entertained and that the Petitioner shall ensure that the unit is

declared under commercial operation by the said date.

8.2.3 NLC had filed Petition before Hon’ble CERC praying that they be permitted to

continue to inject infirm power for testing and commissioning and the time be

extended until 31st March 2015.


July 2014 (refer Annexure-VIII ) had stated that

KSEB had been planning its power purchase annually duly considering the

allocated quantum of power from NLC TPS-II Expansion also, in anticipation of

commissioning the plant. However, due to delay in commissioning of the plant,

KSEB had been forced to avail power through short term markets including

power exchanges at enormous rates and to schedule costly liquid fuel stations

which had affected badly the financials of KSEB and in turn the consumers of

the state.

8.2.5 In the Meeting, MS I/c, SRPC informed that NLC had again filed a Petition for

extension of injection of infirm power until 31st March 2015. CERC had earlier

granted injection of infirm power up to 30th

June 2014. He added that the delay in

commissioning was affecting S1-S2 ATC also.

8.2.6 Director (Tr & SO), KSEB stated that NLC needed to commission the units at

the earliest.


8.2.7 ED (Thermal), NLC informed that after major modifications in fluidized bed heat

exchanger, the unit was synchronized on 13.02.2014. But during loading beyond

120 MW, they had faced problem with tube failure which was studied by M/s

BHEL. The matter was taken up with Secretary (Coal). A Meeting was taken by

Secretary (Coal) and Secretary (Heavy Industries) with participation of officers

from BHEL & NLC. M/s BHEL had committed to modify heat exchanger and

had engaged Swedish consultant. BHEL had committed synchronization of Unit-

1 by mid August 2014. He further added that CoD of Unit-I was expected during

August 2014 and CoD of Unit-II during September 2014. Regarding petition

filed before Hon’ble CERC seeking infirm power injection until 31st March

2015, he clarified that it was with a view to avoid approaching Hon’ble CERC

repeatedly in case any further delays.

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

8.3.1 The following had been noted in the 24th

Meeting of SRPC:

There was no change in schedule and CoD of Unit-I & Unit –II

was expected by October 2017 & April 2018 respectively. PGCIL

had enquired whether these dates were firm since the evacuation

system was to come through TBCB route. NLC had confirmed the

dates.

8.3.2 In the Meeting, NLC informed that CoD of Unit-I & Unit –II was expected by

October 2017 & April 2018 respectively. On a query from POWERGRID, they

confirmed the dates as mentioned above.

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

8.4.1 The following had been noted in the 24th

Meeting of SRPC:

Unit-I had been test synchronized on 22nd

October 2013 with about

160 MW generation and was subsequently taken out from the grid

for statutory checks. Unit-1 had resynchronized at 21.43 Hrs. on

25th

October 2013.

NPCIL had informed that they had obtained permission up to 75%

level. All tests at this level were over except net load rejection test

which was being planned for 18th

March 2014. After verification of

test results by the Regulatory authorities, 90% generation level

would be approved. Additional tests were planned at 90% level and

subsequently only 100% generation level would be approved.

About 8 weeks’ time was expected to reach generation level of

100%. They would approach Hon’ble CERC for injection of in firm

power beyond 6 months. Certain plant parameters at rated capacity

were to be demonstrated by the Russian OEM. Regarding Unit-II, it


was informed that most of the construction jobs were over. Hydro

test for the entire circuit was being carried out at lower pressure.

Reactor Criticality was expected during October 2014 while first

synchronization was planned around November this year.

Additional manpower from other stations was being mobilized for

expeditious commissioning.

8.4.2 In the 96th

Meeting of OCC, KKNPP had informed that the Unit-1 had achieved

1,000 MW on 07th

June 2014.The unit was under shut down and would come

back after 3-4 days. Six tests had been planned at full load/partial generation and

would be completed during a period of 10 days. Subsequently there would be

mandatory shut down for 20 days. The unit was likely be commissioned by July

2014. It was also noted that Hon’ble CERC had accorded approval for infirm

power injection up to 22nd

July 2014. In case COD was expected beyond that

date, KKNPP would need to approach Hon’ble CERC seeking extension.


July 2014 (refer Annexure-VIII) had stated that the

delay in commissioning of the project was seriously affecting the financials of all

Southern Constituents including KSEB.

8.4.4 In the Meeting, MS I/c, SRPC stated that 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. He informed that Unit-I had been taken out for shut down from

16.07.2014. The unit was expected to be back by 16.08.2014.

8.4.5 Additional Director, NPCIL 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.

8.5 BHAVINI- Kalpakkam PFBR (500 MW)

In the 24th


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.

The Reactor could go critical by September 2014 and power injection

expected by November 2014.


8.6 NTECL - NTPC & TNEB Joint Venture - Vallur STPS (3x500 MW)

8.6.1 The following had been noted in24th

Meeting of SRPC:

Unit-I (500MW) had been declared under commercial operation with

effect from 00:00 Hrs of 29th

November 2012 and Unit-II (500MW)

with effect from 00:00 Hrs of 25th

August 2013.

NTPC had informed that Unit-III (500 MW) had been synchronized on

28th

February 2014.CoD of Unit-III was expected by August 2014.

They had identified all activities including RGMO which would be

completed before CoD.

8.6.2 In the Meeting, GM, NTECL informed that the works regarding coal handling

system were held up. NTECL had terminated the contract and the work had been

awarded to a new agency and NTECL was facilitating completion of the coal

handling system at the earliest. CoD of Unit-III was expected by end of August

2014.

8.6.3 MS I/c, SRPC pointed out that level of generation in Vallur was less at times,

which had an effect on the S1-S2 ATC. Realistic generation schedule could be

furnished to SRLDC so as to release the corridor for other scheduled transactions.

8.6.4 ED, SRLDC informed that NTECL had committed 800 MW generation up to 15th

August 2014.

8.6.5 GM, NTECL informed that Unit –II would be under shut down from 15th

to 22nd

August and Unit- I from 23rd

August 2014 for 35 days. Generation would be

maintained around 500 MW level with one unit on bar. There would be some

infirm power injection also. The time schedule etc. would be submitted to

SRLDC.

8.7 NLC Tamil Nadu Power Limited (NTPL- JV Company of NLC

&TANGEDCO) at Tuticorin (2x500 MW)

8.7.1 The following had been noted till 24th

Meeting of SRPC:

NLC had informed that Boiler light up of Unit-I was planned by

March 2014 and CoD was expected by June 2014.CoD of Unit-II

was expected by August 2014.

SRLDC had observed that the data and communication links were

yet to be established and requested completion of pending works at

the earliest.

8.7.2 In the Meeting, ED (Thermal), NLC 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.


8.8 Krishnapattanam UMPP (6x660 MW)

8.8.1 The following had been noted till 24th

Meeting of SRPC:

The project had been awarded to Reliance in the year 2007. The

initial configuration of 5x800 MW was subsequently revised to

6x660 MW with CERC approval. LOI had been placed with M/s.

Shanghai Electric Corporation.

Maharashtra was yet to enter into PPA with CAPL while the other

beneficiaries had signed the PPA.

The generation developer had stopped the works at site and the

project may get delayed.

In the 19th

SRPC Meeting, APTRANSCO had informed that

APSPDCL the lead procurer had tried to encash the bank guarantee.

However, Reliance had approached Hon’ble Delhi High Court and

obtained stay. Hearing on the petition was again held on 31st May

2012. The present developer could be recommended for

cancellation. SRPC may have to approach MoP for entrusting this

project to some other developer.

PCKL had informed that under the leadership of AP all the

procurers had adopted a tough stand. Concerted action had been

taken and once the stay was vacated the bank guarantee could be

encashed. They were also ready with the Caveat in this regard.

After encashing the BG, future course of action could be decided as

per the terms of PPA. Since bidding route was adopted, there was

no scope for revision of the prices and Reliance should have had

proper back to back arrangement for coal supply.

In the 21stMeeting of SRPC, APTRANSCO had informed that they

had conducted a meeting with the procurers. The consensus was to

go ahead as per PPA. However, it was also learnt that the

developer had approached CERC.

In the 22nd

Meeting of SRPC, APTRANSCO had stated that matter

was still pending before the Division Bench of Delhi High Court

regarding termination of the contract. CAPL petition regarding

revision of tariff was also pending before Hon’ble CERC.

In the 23rd

Meeting of SRPC, KPTCL had informed that it was

learnt that though the stay had been vacated, Reliance had

approached the Bench of Hon’ble Delhi High Court. APPCC had

informed that hearings were still going on in Hon’ble Delhi High

Court.

It had been agreed that AP on behalf of other beneficiary states

would take up the matter regarding early disposal of the petitions.

In the 24th

Meeting of SRPC, APTRANSCO had informed that

petition was being heard by Hon’ble Delhi High Court.

8.8.2 In the Meeting it was noted that the matter was pending in the Delhi High Court.


8.9. Cheyyur UMPP (4000MW)

In the Meeting, MS I/c, SRPC informed that it was understood 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.

8.10 Scheduled dates of synchronizing/commissioning of the new projects of NTPC,

NLC, NPCIL, BHAVINI, and Joint Venture & UMPP as noted in the Meeting are

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

September 2015

Unit-II: By March

2016

Construction activities in

progress. Evacuation issues

needed to be addressed.

NLC

Neyveli-II Expn. I 250 CoD by August

2014

Modification of Heat Exchanger

by BHEL

II 250 CoD by September

2014

Work in progress

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 August 2014 Synchronized on 22nd

October

2013

II 1000 March 2015 Work in progress

BHAVINI

Kalpakkam

(PFBR)

I 500 Expected by:

November 2014

Critical by September 2014


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 CoD by August

2014

Synchronized on 28.02.2014

NTPL (JV Company of NLC & TANGEDCO)

Tuticorin I 500 Original schedule:

40 months after

LOA

Anticipated

schedule:

August 2014

LOA signed on 28.01.2009

Commissioning activities started

II 500 Original schedule:

45 months after

LOA

Anticipated

schedule:

September 2014

LOA signed on 28.01.2009

Work in progress

UMPP

Krishnapattanam 3960

(6x660)

Units configured as 6x660 MW.

Amended PPA for 6x660 MW

had been executed with the

procurers. The developer had

stopped the works at site and the

project may get delayed.

Cheyyur 4000 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.

8.11 Statement showing details of MoP allocation/power requirements indicated by

various constituents of SR from the New Projects is furnished at Annexure-X.

9. COAL STOCKPOSITION IN THERMAL STATIONS OF SOUTHERN

REGION

9.1 Need for maintaining statutory coal stock position in all the thermal stations at all

times had been deliberated in various forum of SRPC. Constituents/Generating

Companies had been requested to kindly apprise the Committee of the coal stock

position in thermal stations.


9.2 In the 24th


In the Meeting held on 28th

February 2014, MCL had

committed supply of coal as per programme. MCL had also

sought legal opinion on the MoEF Notification. The Matter

regarding indemnification was also to be considered. Higher

realization of coal supply has been observed in RSR Mode

rather than all Rail Mode. Chairperson, SRPC had taken up the

issues with Member (Traffic), Railway Board.

NTPC had informed that coal being utilized at Ramagundam

STPS was having ash content of around 31-32%.

It was observed that generating stations could suitably blend

domestic coal with imported coal, so as to ensure average ash

content (on quarterly basis) less than 34%.

APGENCO had informed that washery could be installed either

by generators or Coal Company. Washery of 11 MT capacity

was ready for APGENCO and they would avail the facility

shortly. He opined that it would be much easier for coal

companies to establish washeries at the source itself. The cost

in this regard could be borne by the generating companies.

TANTRANSCO had opined that generators in Southern Region

may not get affected since they were utilizing imported coal for

blending. Ash content of imported coal was low.

After discussions, it had been agreed that the matter would be

taken up with the coal companies for supply of washed coal as

per requirements.

9.3 Subsequently, MS I/c, SRPC vide letter dated 24th

April2014 (Annexure -XI) had

taken up the issue with MCL for supply of washed coal as per requirements.

MCL in its reply dated 05.05.2014 (Annexure-XII) had informed that they had a

plan of establishing washery at source itself. In Phase-I, there are 4 (four)

washeries of capacity 10 Mtpa each, which are in pipeline and expected to be in

operation by FY 2016-17 & FY 2017-18. Also for Phase-II, 20 Mtpa & 10 Mtpa

capacity washeries had been identified. The beneficial coal from these washeries

would have ash content of 33.5 ± 5%.

9.4 In the Meeting taken by Secretary (Power) on 6th

May 2014, the need to evolve a

Mechanism to build up coal stock in the power stations was agreed. CIL was to

indicate the sources from where additional coal could be supplied to NTPC

stations/other stations which are having critical coal stock. Ministry of Railways

was to ensure availability of rakes for transportation of additional coal to the

power stations. NTPC was to consider diversion of coal from its power stations


like Farakka STPS, Kahalgaon STPS where adequate coal stock is already

available to its other power stations where coal stock is critical. Adequate stock

of liquid fuel was also to be maintained by NTPC at its RGCCPP plant in

Kayamkulam.

9.5 In the Meeting, MS I/c, SRPC informed that M/s MCL and Railway had been

invited to kindly attend the SRPC Meeting. Railway Board had nominated

Members from East Coast Railway & Southern Railway for the same.

Constituents could take up the issues with Railways appropriately. He further

informed that Unit 6 of Ramagundam STPS was out ( 22nd

July 2014) on account

of coal shortage. Subsequently the unit had been brought back on 25th

July 2014.

He also enquired about the status of diversion of coal from NTPC Farakka &

Kahalgaon to NTPC Stations of SR.

9.6 NTPC informed that diverted coal from NTPC stations of ER had been received

at Simahadri. There was about 60% realization with respect to FSA of Simhadri

from MCL. Supply had been augmented through import of coal for RSTPS and

Simhadri STPS.

9.7 MD, TANTRANSCO noted that cost of power was increasing due to enhanced

usage of imported coal and hence NTPC could try to arrange indigenous supply

as per FSA.

9.8 TCC noted that coal stock position in Vijayawada TPS, Rayalseema TPS,

Simhadri STPS, Ramagundam and Raichur TPS was critical. TCC recommended

that Chairperson, SRPC be kindly requested to take up this matter with Secretary

(Power).

10. LTA QUANTUM IN RESPECT OF UPCL / SCHEDULING OF POWER TO

PUNJAB FROM UPCL (HASSAN – MYSORE 400 KV D/C LINE UNDER

SYSTEM STRENGTHENING SCHEME)

10.1 In the 24th


Hon’ble CERC had passed order dated 20th

February 2014 in

respect of tariff for UPCL valid till 31stMarch 2014. UPCL was

an ISG Station with more than one beneficiary and had

accordingly availed benefits. UPCL should hence initiate

necessary action to ensure that power from the project is

availed by the identified beneficiaries.


UPCL had informed that PSPCL had signed PPA while LTA

had been granted by CTU. It was learnt that PSPCL was

examining the tariff order of UPCL after which Government

approval would be required.

KSEB had stated that in case Punjab was not willing to avail

power, UPCL should take necessary steps to terminate the PPA

and identify another beneficiary. RTA should contain both

Karnataka and Punjab LTA portions, from the date of CoD.

UPCL had opined that LTA granted be cancelled by CTU, if

deemed fit. CTU however clarified that as per Regulations,

beneficiaries were deemed signatories and LTA could not be

cancelled.

TCC had recommended that Chairperson SRPC be kindly

requested to take up with PSPCL for resolution of this issue by

15th

April 2014. In case PSPCL did not revert back favorably,

UPCL could be asked to initiate necessary action for

termination of the PPA and identification of new beneficiary by

30th

April 2014. The following had also been noted:

CTU/ NLDC had not communicated LTA details in

respect of UPCL/KPTCL/PSPCL to be accounted in

Regional Transmission Account/ Regional Energy

Account.

Since the issue (LTA quantum to Karnataka) was not

apparently getting resolved, the affected utility may

need to approach Hon’ble CERC.

10.2 Subsequently, Chairperson SRPC vide letter dated 24th

March 2014 addressed to

CMD, PSPCL (Annexure-XIII)had sought cooperation in resolution of the long

pending issue of scheduling of UPCL power to Punjab.

10.3 Hon’ble CERC had passed orders dated 20.06.2014 in respect of Petition No.

SM/10/2014. This was with regard to non-Compliance of Regulation 8 (6)

Central Electricity Regulatory Commission (Sharing of Inter State Transmission

Charges and Losses) Regulations, 2010. The following had been stated the Order:

“5. In the above background, we direct CTU to clarify its position in

regard to the following:

(a) Whether LTA has been granted to UPCL? If yes, details of LTA

granted and date of its effectiveness.

(b) Whether UPCL has signed the BPTA or long-term access

agreement with CTU? if yes, a copy of the same be placed on

record. If no, the reasons for not cancelling LTA be furnished.

(c) Whether data regarding LTA of UPCL was shared with the

Implementing Agency for PoC computation? If not, the reasons

for not sharing the information may be furnished.


6. It has come to our notice that the matter regarding non-inclusion of

UPCL for PoC computation has been discussed in various meetings

at SRPC Forum. We direct SRPC Secretariat to submit the details

of deliberations held and recommendations of SRPC in this regard.

7. NLDC is directed to explain as to whether non-inclusion of UPCL in

the PoC charges was brought to the notice of CTU and if so, the

response of CTU thereon.

8. SRLDC is directed to explain as to how injection of UPCL is

reflected in the schedule of Karnataka and Punjab.”

10.4 MS I/c, SRPC had vide letter dated 26.06.2014 addressed to Hon’ble CERC

submitted the details of deliberations held and recommendations of SRPC. The

matter was further heard on 8th

July 2014.

10.5 KSEB vide letter dated 14th

July 2014 (refer Annexure-VIII) had requested

review of action taken by SRPC in this regard and present status.

10.6 In the Meeting, it was noted that the matter was before Hon’ble CERC.

10.7 Denial of Consent (NOC) by KPTCL for Open Access for Power Contracted

From Udupi Power Corporation Ltd To KSEB


July 2014 (refer Annexure-VIII) had stated that

KSEB Ltd had contracted 18.5 MW of RTC power from UPCL for the period

1st June 2014 to 31

st May 2015 through Tariff Based Bidding Process. The PPA

was executed on 9th

April 2014. However, KPTCL SLDC has been denying the

NOC for this purpose. It is also stated that Karnataka SLDC had informed that

100% power generated by UPCL is to be made available to ESCOMs of

Karnataka State. UPCL had stated that only 90 % of the plant capacity was tied

up with the ESCOMs of Karnataka. 18.5 MW of power offered to KSEB Ltd.

had not been tied up with any other utility.

10.7.2 In the Meeting, Director (Tr. & SO), KSEB said that 18.5 MW for which no

beneficiaries had signed long term PPA with UPCL had been contracted by

them through Tariff Based Bidding. However, Karnataka SLDC had denied

Open Access and the reason for denial was not clear.

10.7.3 Director (Transmission), KPTCL informed that reason for refusal had already

been communicated by Karnataka SLDC to KSEB.

10.7.4 Additional Director (Projects), PCKL informed that 100% tariff was being

loaded to the beneficiaries (Karnataka and Punjab). Further, during non-availing


of power, if any, by Punjab the first right of rejection was vested with the

Discoms of Karnataka.

10.7.5 UPCL informed that the station capacity had been enhanced from 1,050 MW to

1,200 MW. Punjab had entered into PPA for its 10 % share of 1,050 MW.

Hence 18.5 MW of the augmented capacity (10 % of 185 MW) had been

offered to KSEB. The same had also been intimated to Punjab.

10.7.6 Additional Director (Projects), PCKL pointed out that the tariff petition had

been filed for 1,200 MW (90 % Karnataka & 10 % Punjab).

10.7.7 UPCL informed that tariff petition filed and approved was valid up to 31st

March 2014. Presently, new petition as per provisions of the 2014-19

Regulations notified by Hon’ble CERC was likely to be filed by August 2014.

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

11.1 In the 24th


LANCO had agreed for utilization of the Reactor for voltage

management at Kondapalli. As agreed in the earlier SRPC/TCC

Meeting, energy consumption by Reactor would be considered as

Regional loss. A Meeting with LANCO, SRLDC and SRPC

Secretariat was also held in this regard.

NPCIL had made a presentation on the voltage/tripping issues at Kaiga

GS NPCIL had expressed concern over the frequent trippings of 400

KV Kaiga-Guttur lines and requested that recommendations of

Protection Committee be implemented urgently. They had also

requested that installation of bus reactor at Guttur be expedited by

KPTCL.

CTU had informed that they were examining the issue regarding 125

MVAR reactor at Kaiga and would furnish their comments shortly.

11.2 Updated information in the meeting in respect of pending Bus/Line reactors to be

commissioned by the SR constituents as identified in the 22nd

Standing

Committee Meeting on Power System Planning of Southern Region, and as

approved in the 4th

SRPC Meeting held on 7th

June 2007 is furnished below:

Entity Bus Name Status

KPCL Raichur TPS By October 2014

KPTCL

Hoody

By October 2014 Davanagere

Nelamangala

Talaguppa


KPCL informed that out of 6 foundations, 5 had been completed and

the reactor at Raichur would be commissioned within next 2-3 months.

KPTCL informed that the Hoody reactor had been erected and oil

filtration work was being undertaken. BHEL was not responding

despite the issue being followed at the highest level. In case BHEL

comes forward all the pending works were likely to be completed

within 2 months.

Lanco informed that the reactor at LKPL had been put in service on 7th

July 2014 for voltage regulation of SR Grid in line with the decision in

the earlier Meetings.

TCC placed on record the efforts of LKPL and SR-I PGCIL in making

available the LKPL reactor for regional use.

MS I/c , SRPC informed that the issue regarding 125 MVAR reactor at

Kaiga would be discussed in the 37th

Standing Committee Meeting.

11.3 Details of other Bus / Line Reactors /Dynamic Compensation approved in the

Standing Committee / SRPC are furnished below:

Entity Bus Name

Capacity

in

MVAR

Approved

in Type Remarks

PGCIL

Vijayawada 2x125 20

th SRPC/

34th

SC Bus

Likely

commissioni

ng during

December

2015- March

2016

Nagarjuna Sagar 125 21

st SRPC/

34th

SC Bus

Narendra 125 21

st SRPC/

34th

SC Bus

Hyderabad 125 21st SRPC

Gooty 125 22

nd SRPC

/ 36th

SC Bus

Hassan 12

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 2x80 Line

Narendra–

Madhugiri D/C at

each end

4x63 Line


APTRANSCO

Vemagiri 125 21

st SRPC/

34th

SC Bus

By August

2014

Vemagiri 125

36th

SC

Bus

By Dec 2015

(APERC

approval is

awaited)

Kurnool 125 Bus

Kalpakka 125 Bus

TSTRANSCO

Mamidipalli 125 Bus

Gajwel 125 Bus

Sankarapalli 125 Bus

Mehboob Nagar 125 Bus

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

STATCOM being planned at Hyderabad. It was suggested that PGCIL may

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

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

12. AVAILABLE TRANSFER CAPABLITY (ATC) /TOTAL TRANSFER

CAPABLITY (TTC)

12.1 SRLDC vide letter dated 15th

May 2014 (Annexure-XIV) had communicated that

due to large variations in LGB, variability of wind generation and frequent outage

of units , computation of ATC/TTC would be carried out flow gate wise from the

month of May 2014 rather than the scheduling limit which was in vogue.

Accordingly, the ATC/TTC for May 2014 to Aug 2014 had been revised flow gate

basis and is available on NLDC website. Salient points of the

computations/procedures under this methodology are as below:

The actual prevalent LTA & MTOA had been considered for May

2014(from 16.05.2014)

Normative ex-bus excluding the units under prolonged outage had

been considered for LTA calculation


In case of real time congestion of S1-S2 flow gate, following measures

had been proposed:

The constituents would be directed to make the injection/drawal

deviations to ‘Zero’

If deviation of injection/deviation persisted, congestion charges as

per CERC (Measures to relieve congestion in real- time)

Regulations 2009 would be kicked in.

When no significant deviation of injection/drawal but congestion

existed, curtailment of transactions would be effected in the

following order:

a) URS power from generating station of S1(on pro-rata basis)

to S2 constituents

b) STOA(on pro-rata basis) of S2 constituents

c) After exhausting STOA curtailment, MTOA (on pro-rata

basis) of S2 constituents.

Reallocation of URS power followed by Contingency Applications

would be considered based on ATC declared on NLDC website

subject to margins available.

Revision of ATC would be done in case of ISGS unit outage for

longer duration and sustained LGB changes (to be intimated in writing

by constituents) which may necessitate a relook into ATC/TTC. The

same would be published as a revision in NLDC website.

Any condition like line outage/tripping which necessitates downward

revisions of ATC/TTC for the period of outage would be displayed on

the homepage of SRLDC website as a marquee and curtailment would

be effected.

12.2 The following are the issues which had been deliberated in OCC Meetings:

Availability of units not under COD would not be considered for

ATC/TTC computations.

Constituents specifically KSEB & TANTRANSCO had raised issues

on TTC/ATC in real time on S1-S2 seam. Some include instances of

curtailment of scheduled transactions citing N-1 violations while others

include non-approval of CA/DA/URS applications though real time

margins were available.

For any change of status in Transmission line, Generator etc which was

not considered while computing ATC, SRLDC had agreed to carryout

studies accordingly and revise ATC for the rest of the period.

SRLDC had informed that Real Time TTC/ATC would not be

computed by them and the matter was to be taken up with NLDC.

Regarding real time flows for revision of ATC, SRLDC had stated that

ATC declaration was for future time horizon. In case of significant

change in LGB for longer duration, the responsible constituent/s may


submit revised LGB for a specific period, preferably on day ahead basis

for validation of SRPC and subsequent revision of ATC by SRLDC.

SRPC had clarified that there was no role of SRPC Secretariat for

validation in real time or on day ahead basis. Neither any Regulation

mandated such requirement nor did they have the infrastructure (24 hrs

Control Room) to take up such works. Clause 4.5 of Detailed Procedure

for Relieving Congestion in Real Time Operation was brought to kind

notice as reproduced below:

“ NLDC may revise the TTC/TRM and ATC due to change in

system conditions(including commissioning of new

transmission lines/generation), vis-à-vis earlier anticipated

conditions which included change in network topology or

change in anticipated active or reactive generation or load at

any of the nodes in the study. Revisions may be done by NLDC

based on its own observations or based on inputs received

from SLDCs/RLDCs. Revised TTC, TRM and ATC shall be

published on website of NLDC and RLDCs along with reasons

thereof. ”

On perusal of the above, it can be seen that ATC/TTC may

have to be revised in real time even for Load Generation

Balance change. There was no role of SRPC Secretariat after

LGBR validation on monthly basis.

The following was also noted from Para 54 of Order dated 22nd

February 2014 in respect of Petition No. 167/Suo-Motu/2012 as

reproduced below:

“ NLDC further states that Enquiry Committee has recommended

the following:

NLDC and each RLDC should have one real-time security desk in

all the shifts to be manned by engineer capable of carrying out TTC

calculations. To facilitate this, manpower at NLDC and RLDCs

need to be enhanced with regulatory support to take care of

financial aspects. Till this arrangement can be firmed up, various

scenarios of outages could be built, which then can be used by

despatcher in real time. Faster algorithm for calculation of TTC

may be adopted by the load despatchers to update it in real time

under outage conditions. Post disturbance NLDC/RLDCs are

taking up the above recommendation for manning of security desk

at each RLDC and NLDC by engineers capable of carrying out

TTC calculations….”

SRLDC had observed that System Studies / Security analysis being

carried out in real time are primarily meant for demand management,

clearance of emergency outages, averting any eventuality due to lack of

meeting n-1 criteria etc.

Need for having quality node wise data from the constituents (for 96

time blocks / different scenario like peak / off-peak) was also


emphasized before computation of ATC for optimal utilization of

transmission system. Constituents were requested to furnish Block

wise/Day-wise LGBR figures (Node-wise) for the coming five months

and the system should be in place by September 2014.


July 2014 (refer Annexure-VI) has stated a

migration of TTC methodology to flow gate all of a sudden has been done by

SRLDC without discussion in any forum. Further, the method adopted has not been

described to the SR constituents. Levy of congestion charges would only add

commercial burden to the constituents and would not be the proper solution for

restricting overloading of line. Therefore, instead of applying congestion charges,

curtailment of STOA power, URS and MTOA power should be made.

12.4 In the Meeting, MS I/c, SRPC informed that the issue had been deliberated in

various forums/OCC meetings. It was perceived that there were no issues regarding

study part, and issues pertained to procedure, real time ATC, curtailments etc. As

per Congestion Regulations SLDC’s had to carry out the computations of

TTC/ATC of their intra-state system keeping in view load generation balance. They

needed to furnish node wise LGB details to RLDC. However, except KSEB no

other state was furnishing the details to SRLDC. It had been agreed in the OCC

forum that node wise/day wise/period wise/block wise load and generation details

for next 5 months were to be furnished for validation. SLDC’s had expressed

constraints stating that dedicated studies team was not available with them and they

were facing manpower crunch. Dedicated system studies group was necessary for

this purpose.

12.5 ED, SRLDC stated that real time flows could not be considered for release of ATC.

SRLDC was always trying to optimize flows keeping in view the grid security.

Input data in the requisite format was not being received from the SLDCs. Block

wise/node wise data could be furnished which may enable release of higher ATC

during off peak hours. Such inputs and cooperation of SLDC’s would enable

RLDC/NLDC to compute ATC in a more scientific manner.

12.6 CE (O), TANTRANSCO enquired about furnishing of similar information by other

states in other regions. He opined that furnishing node wise data was difficult. He

informed that they were having more than 100 nodes at 230 KV level. He therefore

suggested that system for furnishing node wise data could commence at 400 kV

level.


12.7 Director (Tr. & SO), KSEB pointed out that the net ATC to S2 constituents had

been reduced from 15th

May 2014. This happened due to migration to flow gate

based methodology without any proper justification. During real time, the flows

were less than the ATC. Hence, additional corridor needed to be released to ensure

that transmission assets are utilized optimally.

12.8 ED, NLDC informed that Regulations mandated computation of ATC/TTC by

SLDCs in respect of their control area. While carrying out this exercise, Punjab had

realized the constraints in the intra state network and power procurement was done

accordingly. Gujarat though being surplus state with good wind generation had

observed intra-State constraints. In the interest of constituents, more than 30 to 50

revisions were being done monthly so as to optimize utilization of the corridor.

More validated data in the requisite format would help in assessment of ATC/TTC

more accurately.

12.9 TSTRANSCO informed that for proper ATC/TTC computation by SLDC, firm and

accurate inputs of load and generation etc were required from the Discoms and

State Generating Companies. In the absence of Intra-State ABT, there was some

degree of uncertainty in respect of embedded generators. Generators were citing

poor coal quality/shortage, restrictions on sudden variations in loading etc as

constraints. Hence the entire system needed to contribute accurately in turn to

enable SLDCs to furnish realistic ATC/TTC computations to RLDC.

12.10 TANGEDCO stated that a pragmatic and practical view was very essential to take in

this regard. All constituents were expressing the constraints in furnishing the data

desired by SRLDC. The matter was needed to be taken in the appropriate forum so

that necessary amendments could be suggested and implemented in the Regulations

12.11 Director (Tr.), KPTCL suggested that issues in this regard be further discussed in

the proposed TCC meeting.

12.12 After deliberations it was agreed that the issue would further be discussed in the

Special Meeting of TCC. In the Special meeting, constituents would revert back on

the issues being faced (with facts/figures) with regard to the data to be furnished by

SLDC. SRLDC would also present about the need for getting such data for ATC

computations.


13. IEGC RELATED ISSUES

13.1 Restricted Governor Mode of Operation (RGMO)/FGMO of Generating

Units & MVAR Interchange

RGMO response had been deliberated in various Meetings held on the issue. The

issue had been further highlighted in the 23rd

/24th

SRPC Meetings. Inadequate

response is an area of serious concern and there was no noticeable improvement. In

this regard, there is an ongoing Petition (No.302/MP/2013) being heard by Hon’ble

CERC. The issue was further deliberated in the Meeting held in MoP on

13.01.2014 & 07.02.2014. RGMO response was again analyzed in a Special

Meeting on RGMO/MVAR held on 23rd

June 2014 with participation from CERC

staff.

The Summary of deliberation is as follows:

It was noted that response at times being reported by generators was

in variance with the response being observed by the SLDC/SRLDC.

Data validation was thus needed to be carried out between state

generators and the respective SLDCs and the ISGS generators and

SRLDC.

DC declaration by generators could be made appropriately to ensure

RGMO response. State Load Despatch Centers could also schedule

appropriately so as to ensure the response.

Ramagundam to study the RGMO response of its units and

specifically Unit-7 and revert back with details.

It was suggested that the STOAs should not be transacted/permitted

by SLDC beyond MCR to ensure that response is available for

purpose of grid security.

KPCL to appropriately take up the issue regarding up rating/installed

capacity of Nagjheri units.

Reasons for non-performance needed to be qualified with proper

technical justification by the generators.

TTPS to discuss with M/s NTPC/BHEL regarding implementation of

RGMO in Unchahar and Korba and compare the scheme provided in

TTPS.

All technical issues needed to be taken up with OEM and concrete

action plan to be ensured within two months.

It was noted that instances of frequency excursion were still

continuing. States were therefore requested to stagger the

changeover and minimize the effect on the Regional Grid/generators.

It was recommended that all the stations should have data logging

facility (up to six months) for fruitful analysis/deliberation.


RGMO should always be in service including at technical minimum.

Generators to initiate steps to ensure visibility of RGMO status in

the SCADA.

Parameters needed to be maintained so as to ensure that RGMO

response is available at all instances.

SLDCs to take proactive role for RGMO implementation/

monitoring.

TN SLDC to ensure participation/data furnishing from STCMS units

also.

KSEB was suggested to ensure FGMO response of balance units not

under FGMO, through their internal maintenance team, wherever

possible.

It was noted that individual GENCOs needed to approach through

petition to Hon’ble CERC for obtaining any exemption/extension of

RGMO/FGMO compliance.

In accordance with RoP on Petition No.302/MP/2013 all SLDCs

need to furnish the following on affidavit by 6th

July 2014:

Report with details of RGMO/FGMO response of each

generating station within their control areas and

Details of having taken up the matter with respective SERC

in case lack of response or inadequate response from the

generating units within their respective states.

In the Meeting it was again suggested that SLDCs may take up with

their respective State Commissions the lack of response/inadequate

response of the generators of their control area.

In accordance with RoP on Petition No.302/MP/2013, TANGEDCO

and APGENCO had been directed to submit on affidavit detailed

note explaining how irrigation requirement is coming in the way of

implementation of FGMO/RGMO, after discussing the matter, if

required, with their State Irrigation Department by 6th

July 2014.

It was suggested that the GENCOs/SLDCs may please take up the

issue with their Irrigation Department.

Adequate RGMO response and UFR/df/dt relief in other regions was

also required to be ensured / monitored to avoid sudden change of

direction of flow on 765 KV Raichur-Sholapur line. NLDC/SRLDC

were requested to take steps accordingly.

In the OCC Meetings, constituents had expressed that 40% ideal

response in FRC computation was not appropriate in present Indian

power scenario. FRC computations for load/generation change of

more than 1,000 MW could be considered for enhancement since

NEWS Grid had been operational.


Generators were expected to give response of 5% of the current

generation subject to 105% of MCR and analysis would be carried

out accordingly for new instances.

13.2.1 In the Meeting, ED, SRLDC stated that SLDCs were not according due

importance to analysis of RGMO performance. It had been observed that the

response was only upto about 40 to 50 %. SLDCs had therefore to play a more

proactive role in this regard.

13.2.2 MS I/c, SRPC pointed out that inadequate response was required to be taken up

with concerned SERC by SLDCs. Visibility of RGMO status in SCADA was also

required for better monitoring. Taking out of RGMO if at all was needed to be

carried under due intimation to RLDC/SLDC along with valid reasons.

13.2.3 ED, NLDC informed that in the recent meeting of NRPC, it had been decided that

RLDC would broadcast 2 to 3 instances every month. The generating stations

would furnish their response to RLDC/RPC for analysis/validation. MS I/c, SRPC

informed that similar practice was already in vogue in SR. A Group had been

formed where the instances were getting posted. A number of Meetings had

already been convened.

13.2.4 TS SLDC observed that the Southern Region states were facing power deficit.

Decision regarding sacrificing of 5% generation so as to ensure RGMO response

was needed to be taken up at SRPC level also. Also, there was no margin

available at times with all mills in operation due to poor fuel quality.

13.2.5 NTPC stated that response at that instant may vary with respect to coal quality

and system parameter. Hence, to expect 5 % response in all instances may not be

feasible.

13.2.6 Chairperson TCC, observed that adequate RGMO response was very necessary

for Grid stability. He urged that generators make all efforts to improve the

response. Unit wise response etc could be deliberated in the special RGMO

Meeting. He added that there should a sense of urgency for improvement of the

RGMO performance.

13.2.7 After deliberations, the following was summarized:

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.


13.2.8 Regarding MVAR, the action plan recommended in the Meeting held on

23rd

June 2014 is furnished below:

GT tap positions to be changed as per recommendations. All other

stations to ensure their GT Tap positions are optimized so as to bring

Grid Voltages to Nominal values.

Respective SLDCs would monitor VAR Interchange of the generators

in their control area and also ensure better voltage profile.

Respective SLDCs would participate in reactive power demonstration

testing along with the testing team for the units under their control

area.

SRLDC could issue messages for Violation under IEGC clause 6.6.6

All Generators agreed to initiate timely action on the

recommendations. Dates of Tap changes and set tap positions need to

be communicated to SRPC/SRLDC as and when changes are carried

out. Same should also be reflected in the information which would be

furnished for future analysis

400kV Tap changing is to be carried out only after due concurrence of

SRLDC.

Number of Generators were not furnishing timely information in

correct format. It was suggested that information should be furnished

in a timely manner.

Calibration of meters to be under taken so as to ensure accurate

visibility of the parameters to the plant operators.

Limiter setting would be as per the capability curve.

Some of the stations AVR voltage control was not going to± 5%. The

same would be examined and rectified.

Stations could themselves conduct reactive demonstration, periodically

as per the agreed procedure.

It was agreed that the demonstration of MVAR would be carried out

only up to 95% of the rated auxiliary voltage.

MVAR data to be posted on [email protected]. Data for

state generators needed to be validated by the respective SLDC.

It was recommended that all the stations should have data logging

facility (up to six months) for fruitful analysis/deliberation.

Any, change in capability curves w.r.t. data furnished for MVAR

document would be communicated. Wherever CC is not clear,

information could be sent in table format also.

The following had been noted in the 24th

SRPC meeting :

SRLDC had also informed that MVAR demonstration had been

carried out at Srisailam (LB and RB) and Vijayawada units.

Against MVAR absorption capability of 100 MVAR/unit, units at

mailto:[email protected]


Srisailam were absorbing only about 60 MVAR each. APGENCO

had been requested to take up this matter immediately with the

OEM. Higher absorption would help improve the voltage profile

with use of existing resources itself. MVAR absorption by VTPS

(500 MW) unit had improved to about 140 MVAR as against

earlier level of about 70 MVAR. MVAR demonstration had also

been carried out at Raichur, Kadra, Kodasalli and Nagjheri units of

KPCL. Calibration of all the meters (other than Energy meters

also) and data logging facility was however highly necessary.

Testing at Raichur TPS could not be completed on account of

mismatch of system parameters in various meters. It was also

requested that the concerned generators may study the reports and

arrange for necessary remedial measures.

13.2.9 In the Meeting MS I/c, SRPC requested the constituents to kindly comply the

decisions taken in various Meetings in this regard.

13.2.10 ED, SRLDC informed that Raichur STPS was yet to rectify the mismatch between

SCADA and generator meter data which was observed during the MVAR testing.

KPCL informed that works had been taken up and would be completed in 3 to 4

months.

13.3 Arranging of interruptible loads in four groups

In the OCC meetings, it was noted that 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.

SRLDC & SRPC Secretariat pointed out that existing schemes

were not meeting the Regulatory requirement fully and further

action was required in this regard.

13.4 Automatic Demand Management Schemes

13.4.1 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 requirement.

13.4.2 In the 24th

SRPC Meeting the following had been noted :

Hon’ble Commission’s Order dated 18.12.2013 in respect of Petition

No. 208/SM/2011 was noted.


In CERC’s Order dated 22nd

February 2014 in Petition No. 120/2011

regarding Maintaining grid security of the Southern Regional Grid

by curbing over drawal and effecting proper load management by

Tamil Nadu Electricity Board the following had been stated:

Respondent to take necessary steps to implement automatic

demand management scheme to deal with the emergency

situations such as sudden variation of wind generation or

forced outages etc. and submit the monthly progress report

to SRLDC and SRPC in this regard.

SRPC shall inform the Commission about any deficiency in

the action taken by the respondent and non-compliance

with the directions of the Commission.

TN was to submit monthly progress report to SRPC and

SRLDC.

13.4.3 In the OCC meetings the following had been noted:

KSEB vide their letter dated 20th

May 2014 had informed that

ADMS has been implemented. Kerala had been requested to

demonstrate the functioning of ADMS to SRPC/ SRLDC.

TANTRANSCO had informed that they had identified the feeders

of quantum of 650 MW and the P&C wing of TANTRANSCO was

implementing the scheme.

All the SLDCs except KSEB had been requested to finalize the

scheme and get it approved through their management for

implementation by June 2014 end.

13.4.4 Hon’ble CERC had heard the Petition No 005/SM/2014 on 22nd

May 2014. In

the RoP, it had been stated that the Commission observed that despite

understanding the scheme technically, SLDCs are not implementing the

scheme which is of national importance. The Commission had directed the

respondents to implement ADMS in pro-active manner and approach the

Commission if they face any difficulty in implementation of scheme. The

Commission had also directed the respondents to submit on affidavit, by 30th

June 2014 an action plan and PERT chart clearly mentioning the targets and

deadline to achieve the same, with an advance copy to RLDCs.

13.4.5 In the Meeting, MS I/c, SRPC informed that 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.


13.4.6 Director (Tr.), KPTCL 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.

13.4.7 Director, APTRANSCO informed that 60 RTUs had been planned to be

installed and they were also planning to have a Meeting with DISCOMs to

finalize ADMS.

13.4.8 AP & Telangana informed that the new upgraded SCADA system was likely

to be in place by October 2014 and ADMS would be subsequently

implemented.

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

13.4.10 Director, TANTRANSCO informed that 650 MW of loads (110 KV radial)

had been identified and logic had been received by P&C wing and they were

on the job. The scheme was expected to be operational by October 2014.

13.4.11 ED, SRLDC stated that ADMS for TN should also address the sudden

variations of wind generation.

13.5 Automatic Load Disconnection Schemes for overdrawing constituents

In the 14th

Meeting of SRPC held on 27th

August 2010, it had been agreed to

implement Automatic Load Disconnection Scheme for overdrawing constituents

with the following relief:

Sl. No. Constituents Load Relief

1 APTRANSCO 450 MW

2 KPTCL 350 MW

3 KSEB 125 MW

4 TANTRANSCO 650 MW

5 Puducherry 25 MW

It was noted that the Automatic Load Disconnection Scheme was part

of Automatic Demand Management Scheme.

States had been requested to ensure adequate load relief in the interest

of grid security.

SRLDC & SRPC Secretariat had pointed out that the scheme needed

to be in automated so as to meet the Regulatory requirements.

13.6 Sudden Change in Drawal/Frequency Excursion

13.6.1 States had been requested to adhere to drawal schedule and also not to under

draw during high frequency conditions.


13.6.2 In the earlier Meetings, SRLDC had brought to kind attention provisions of

clause 5.2 (j) of the IEGC Regulations. No user was 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.

13.6.3 SRLDC had been reporting instances of violation of IEGC clause 5.2(j) with

the constituents for necessary compliance. In the 96th

Meeting of OCC,

SRLDC had stated that the issue of sudden change in drawal pattern to

extreme level was being continuously taken-up under IEGC clause 1.5 but the

improvement of situation was not to the desired level. During load

changeover, it had been observed drawal deviation vary between – 300 MW to

+300 MW in many instances. Proper implementation of ADMS and

staggering of loads was essential to avoid sudden changes in load. In the

absence of effective RGMO / FGMO, the changeover impact was getting

reflected in inrush of flow on critical lines and was posing threat to security of

the grid. Hence, the constituents had been requested to kindly ensure strict

compliance of IEGC by ensuring the changes not more than 100 MW and also

to ensure smooth load changeover in a staggered manner to avoid sudden

changes. In case, the situation did not improve to the mandated level, SRLDC

may be constrained to approach Hon’ble CERC in this matter.

13.6.4 In the Meeting, ED, SRLDC expressed concern that despite this issue being

flagged in various forums for the past two years, the load change over

staggering still needed refinement. Earlier the problem was restricted to SR

alone but was now getting reflected on flows on Raichur-Sholapur link. Thus,

it was affecting operation in other Regions also. Summary of violation

messages issued by SRLDC in this regard is furnished at Annexure-XV

13.6.5 Director (Tr.), KPTCL said that with increases in size of the system and EHV

lumped loads coming and going out of the system, it was difficult to manage

sudden variations in loads. Earlier, changeover in BESCOM was coinciding

with changeover in GESCOM which had been staggered to avoid sudden

jumps.


13.6.6 MD, TANTRANSCO said that it was very difficult to manage such

limitations during high wind conditions. About 1,200 MW of unscheduled

load shedding was being carried out at times.

13.6.7 CEO, JSWEL said that this issue had to be seen keeping in view the tie up of

power purchase in different time blocks. Presently more tie ups were for RTC

power, with wide load variations in the system, leading to such variations.

13.6.8 Chairperson, TCC stated that SLDCs needed to monitor change overs

meticulously and requested them to comply with the Regulations and avoid

sudden changes in the drawal pattern.

13.7 Inadequate UFRs and df/dt reliefs

13.7.1 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 1.5 of IEGC on a number of occasions. SRPC

Secretariat had taken up the matter with Constituents for necessary

compliance.

13.7.2 On 19th

December 2013,Hon’ble CERC had issued its Order in respect of

Petition No 263/MP/2012.It had been 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. Compliance Report duly certified by SRLDC and

SRPC was to be submitted regarding implementation of quantum of relief of

AUFR as per the table furnished in the Order and also proper functioning of

df/dt relays within one month of issuing the Order. SLDCs had also been

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

issuance of the Orders. The certified relief quantum by SRLDC and SRPC

had been furnished to the constituents.

13.7.3 In the OCC meetings, it had been noted that in compliance of orders of

Hon’ble CERC, SRPC vide letter dated 23.04.2014 had communicated

compliance report in respect of the following:

Status of the additional identified loads which were to be

implemented.

Status of additional loads to be identified and implemented.

Status of SCADA mapping and the action plan to achieve 100 %

mapping.


SRLDC has been continuously monitoring on its SCADA system the feeders

connected with AUFR & df/dt protection (as available in SCADA). This has

been done to ascertain the extent of protection available in the event of any

contingency. SRLDC has also been addressing regular communications in this

regard conveying the observations. The matter regarding in adequate quantum

of relief is being constantly reported by SRLDC under clause 1.5 of IEGC.

13.7.4 In the Meeting ED, SRLDC presented the status of SCADA mapping and visible

relief (Annexure-XVI). He expressed concern over the moderate quantum of relief

visible. ED, NLDC said that absence of strong safety net also inhibited release of

higher TTC/ATC. Only about 70% relief was visible and in real time it was always

in doubt whether any untoward incident could be managed.

13.7.5 CE (O), TANTRANSCO said that most of the feeders had been identified for

various schemes and availability of radial feeders was limited. He added that the

relief provided was adequate for the purpose of grid security. Expecting constant

relief all the time did not appear feasible keeping in view variability in loading of

the feeders. Actual relief at any instant would naturally be based on the prevailing

load on the system. The expected relief should have some correlation with the

system load and could not be constant.

13.7.6 MS I/c, SRPC said that the relief figures had been finalized by NPC as per the

recommendations of Zhalte Committee. 1Hz jump had been envisaged at each of

the four stages. Relief was to be ensured on average value as directed by Hon’ble

CERC. Relief could also be provided at lower voltage levels as had been

implemented by KSEB.

13.7.7 KSEB informed that they had gone up to 11 kV level and overlap had also been

avoided.

13.7.8 Chairperson TCC, suggested that the visible reliefs/reliefs provided be reviewed by

SLDCs in consultation with Discoms.

13.7.9 After deliberations SLDCs were 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.


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

13.8.1 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.

13.8.2 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.”

13.8.3 In the 24th

Meeting of SRPC it had been noted that day ahead (block wise)

demand forecast along with portfolio management was to be displayed in

website of SLDCs as per directions of MoP.

13.8.4 In the meeting the following was noted:

KSEB informed that they were displaying the Demand forecast on

their website

KPTCL informed that they were sending the information to

SRLDC/SRPC through e-mail

TANTRANSCO observed that they were ready to share information

with SRLDC/SRPC but were constrained not to share this

information in public domain.

13.8.5 SRPC Secretariat pointed out that Demand forecasting tool for operational

purposes was yet to be developed to meet regulatory requirement.

13.9 Low Voltage and installation of UV Relay

13.9.1 In the earlier OCC Meetings the following had been noted:

SRLDC had expressed concern about the low voltages in Mysore,

Bangalore, Udumalpet, Madakkathara, Palakkad, Kochi and North

Kerala areas.

KPTCL had informed that higher management had been apprised of

the UV relays requirement. In order to maintain the voltages, they

were taking immediate actions and all the circles had been directed

to rectify/replace faulty capacitor banks and directives had been

issued in this regard. Tenders had been floated for procurement of

500 MVAR Capacitor banks for which budget provisions was also

made.


KSEB had informed that a scheme to implement the UV relays had

been prepared and would be finalized within a couple of weeks.

SRPC and SRLDC had suggested that specifications mentioned in

the NLDC document (Stage I: V < 200 or 198 (IEGC) KV for more

than 5 Minutes, Stage II: V < 185 KV for 30 seconds) for GSES

maybe followed in this regard.

TANTRANSCO had informed that 1,005 MVAR of capacitors at

distribution level were under various stages of installation.

In the 96th

OCCM, after deliberations, it had been concluded to

identify list of feeders that may be suitable for physical regulatory

measures by SRLDC in case of consistent low voltage situation at

specific nodes since there was delay in implementation of Under

Voltage Relays which was IEGC mandated provision and approved

by SRPC in earlier meeting. This interim measure of physical

regulation may be implemented till installation of sufficient

capacitors / UV relays. All the constituents had been kindly

requested to furnish action plan for installation of UV relays by

26.06.2014, else physical regulations may need to be taken up in the

interest of system security.

13.9.2 In the Meeting, MS I/c, SRPC informed that despite earlier approval of SRPC

regarding UVR implementation, there had been no progress in Karnataka and Tamil

Nadu. Karnataka and Tamil Nadu were however informing about the progress of

capacitor installation. KSEB had finalized the scheme which had been put to higher

management and approval was awaited.

13.9.3 ED, SRLDC 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. In the OCC Meeting the list of low voltage nodes and the proposed feeders to

be tripped for voltage regulation had been discussed.

13.9.4 Director (Tr), KPTCL agreed to implement UV relay scheme. He added that steps

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

13.9.5 CE (O), TANTRANSCO said that they would maintain the voltage levels within

limits at 230 kV level and below. SRLDC should monitor the voltage level at 400

kV level. He added that with commissioning of a number of 400 kV lines, the

voltage profile had improved. 400 kV Chittor – Thiruvalam line was even tripping

on high voltage.

13.9.6 MS I/c, SRPC observed 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.


13.10 Low Voltage Ride Through (LVRT)

13.10.1 In the Meeting, MS I/c, SRPC informed that 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 (recommendations at Annexure-XVII).

13.10.2 MD, TANTRANSCO informed that the old generators were getting phased out and

new generators were coming up. Lot of capacitor installation was also being

undertaken to improve the voltage profile. Wind generation was also being backed

down to contain voltage fluctuations. The matter regarding provision of LVRT

features was being taken up with the wind developers.

13.10.3 ED, NLDC stated that sudden loss of about 1,000 MW of generation due to

uncleared faults/voltage dips was a serious threat. This assumed greater

significance since it would reflect in sudden inrush of power towards SR on

Raichur-Sholapur link. Hence, TN needed to take up the issue of LVRT/FRT in a

time bound manner so as to ensure that grid security is not endangered. This was

especially required since around 7,000 MW of wind generation was already

installed in the TN grid.

13.10.4 Director (Tr), KPTCL 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.

13.10.5 ED, SRLDC said that action with regard to the Report on Low Voltage in

Udumalpet was awaited from TANTRANSCO. TANTRANSCO informed that 24

MVAR capacitor out of 120 MVAR had been installed in Udumalpet area and

works were under progress for balance capacitors. In addition capacitors at

distribution level were also being added. Further, 200 MVAR of dynamic

compensation would be commissioned by PGCIL at Udumalpet. They requested

for early commissioning of the same. It was also informed by TN that LVRT

characteristics would be provided in the windmills (around 7,000 MW) before the

wind season next year. Presently about 1,087 MW of wind mills were equipped


with this characteristics.

13.10.6 After deliberations, it was agreed that new upcoming units would be ensured with

LVRT features as mandated under the Regulations. Tamil Nadu & Karnataka

were requested to kindly take up the recommendations finalized in the Meeting

held on 08th

July 2014.

14. OPERATION OF FILTERS AT HVDC KOLAR

14.1 In the OCC meetings, it had been pointed out by SRLDC that Kolar Control

Room was refusing to switch on the filters (capacitors) on being directed by

SRLDC in order to control low voltages. SRLDC had suggested PGCIL to switch

on the filter banks at Kolar HVDC when the Kolar bus voltage falls below 395 kV

as per the real time directions of SRLDC as was being done earlier. PGCIL had

stated that set point of capacitor filters were set in 20 kV band in the range 390 –

410 kV. All the logics were in auto mode and there was no scope for manual

intervention. Manual intervention had earlier lead to failure of number of

capacitor bank and hence manual switching was not recommended. PGCIL had

informed that the issue regarding changing the range to 395-415 kV and changing

the band of 20 kV to 15 kV had been referred to M/s Siemens. The OEM had not

accepted for the recommended changes. OEM had expressed that there could be

damages to breakers, filters etc at higher level of the band.

14.2 SRLDC had requested POWERGRID to furnish details of manufacturer’s

response. The case needed to be understood at par with generator’s capability

curve, performance possibility etc. This would facilitate to understand/suggest

any modification / additional requirement of software / hardware items that would

help power system to operate in an efficient manner.

14.3 In the Meeting, ED, SRLDC said that Somanahalli & Hoody voltages were low

and maximum MVAR support from Kolar would help in improving voltage

profile.

14.4 GM, PGCIL informed that changing of band from 390- 410 kV to 395- 415 kV

was not accepted by the OEM. It was pointed out that the availability of the

Talcher-Kolar link was more than 99.90 % and even 100 % in many months with

the cooperation of the states, SRPC & SRLDC. This link was very vital for


system operation. It was carrying maximum power flow of 2,300 MW on a daily

basis. Initially a number of capacitor filters had failed due to wear and tear/stress.

From the design point of view and keeping in view long term reliability, it was

not desirable to change the existing set points. It was also to be borne in mind that

the system had aged.

14.5 After deliberations, it was agreed that the existing set points would be continued.

15. KKNPP RELATED ISSUES

15.1 A Special Meeting was held on 12th

March 2014 at SRPC Bangalore to deliberate

on the issues related to KKNPP. The following issues needed resolution:

Implementation of SPS during Tripping of ATS

KKNPP vide letter dated 06th

June 2014 had informed regarding manual

reduction of generation of KKNPP at 50 MW/Min in contingency. It

was once again pointed out the scheme of 50MW/min manual reduction

may not be adequate to ensure the unit survival. The scheme needed to

be automated.

Auto reclose with 11/2 Breaker scheme

SRLDC stated that A/R scheme needs to be implemented before

CoD of unit.

Hot line link between KKNPP and SRLDC

KKNPP had informed that approval for hotline link to SRLDC had

been received and the same would be commissioned shortly.

SCADA Inputs to be ensured from KKNPP

Regarding the pending SCADA input to SRLDC, alternate method

was being studied by KKNPP and they would revert back.

Spurious generation of SPS signal at KKNPP

SR II, PGCIL had completed the necessary modifications.

Interpretation of Capability Curve(limiting MVAR absorption to 100

MVAR)

KKNPP stated that the issues had been taken-up with concerned

agencies and they would revert back soon.

Status review of changing GT tap position at Kudankulam NPP

corresponding to 400 KV & Review of absorption / injection of

MVAR

KKNPP had stated that the issues had been taken-up with concerned

and would revert back soon.


15.2 In the Meeting, the following was noted:

NPCIL informed that SPS was being reviewed by the designer. In the

interim period, SPS with 100 MW/minute manual reduction could be

utilized. However, as per their assessment, the unit may not survive even

with provision of SPS on account of power swings.

SRLDC stated that in case manual reduction is resorted, there was every

possibility that the existing line would trip. Thus, the complete

connectivity to the station could be lost. Black Start power could take

considerable time (even one day) since power would have to be supplied

after stabilization of Tuticorin generation.

NPCIL vide letter dated 06.06.2014 (Annexure-XVIII) addressed to

CTU had requested for advancing Tuticorin PS- Tirunelveli D/C line and

connecting KKNPP 1&2 – Tirunelveli D/C thus making it KKNPP 1&2-

Tuticorin PS D/C line. This would ensure that KKNPP 1& 2 would have

two corridors and may not call for operational measures during non-

availability of either of the two terminating stations. It was noted that this

issue would be deliberated in 37th

SCPSPSR scheduled to be held on 31st

July 2014.

NPCIL informed that pending SCADA points through alternate methods

would be completed before COD of Unit I. Hot line link with SRLDC had

been established.

NPCIL informed that Auto Reclose with 1½ Breaker scheme had been

implemented at RAPS. After trial run and getting necessary confidence, it

would also be implemented at KKNPP. NPCIL would try to implement

the same before CoD.

PGCIL observed that Auto Reclose feature had to be enabled on 400 KV

Kaiga-Guttur and Kaiga-Narendra lines also.

It was also noted that PGCIL had carried out modifications in the SPS

settings.

NPCIL informed that as per the designer, 100 MVAR absorption by the

unit was only possible. With commissioning of the second unit, line

loadings would increase and high voltage scenario may be relieved. The

GT tap setting would thus be reviewed after commissioning of Unit 2.


SRLDC pointed that 100 MVAR absorption only in each unit may not be

sufficient to address the high voltage issue. Need for additional reactor at

KKNPP was required to be studied.

PGCIL informed that KKNPP was planned during 2002-03 with

generation expected in December 2007. In view of need of connectivity to

the nearest substation, two D/C 400 kV lines had been planned to

Tirunelveli S/S. Subsequently, in order to improve the reliability, one

Madurai-Tirunelveli line was bypassed and connected to KKNPP. Angular

separation was to be considered for connectivity/evacuation of Nuclear

stations and the line length could not be more. The constraint was coming

up since bypassed Madurai-Tirunelveli line was twin moose while

KKNPP –Tirunelveli portion was Quad. Direct connectivity to Tuticorin

PS was being proposed now to improve the connectivity.

Two reactors of 80 MVAR had been planned. Additional requirement of

reactors may need to be put up to the Standing Committee in view of

limitation of present absorption level as was being stated by NPCIL.

16. ALTERNATE / RELIABLE AUXILIARY SUPPLY AT HVDC

BHADRAWATHI

16.1 In the OCC Meetings it was noted that for a vital element like HVDC Bhadravathi

availability of alternate / reliable auxiliary supply was very critical. The

requirement was in line with CEA Technical Standard on Connectivity to Grid

Regulation. Uninterrupted changeover during failure of existing auxiliary supply

could not happen due to the inherent start-up time lag of DG set. The matter had

been taken up by SRPC with WRTS I, POWERGRID.

16.2 In the Meeting MS I/c, SRPC informed that the reply from WRTS had been

received. (Annexure-XIX) 315 MVA ICT had been planned and award had been

placed in October 2013 by WRTS PGCIL.

16.3 ED, SRLDC informed that there were two more instances on 6th

and 9th

July 2014

of blocking of HVDC poles at Bhadravathi. The number of such instances was

about 7 since 2013.

16.4 ED, SRTS-I, PGCIL said that they would revert back in this regard.


17. PSS TUNING /SYSTEM STUDIES

17.1 SRLDC had suggested that to prevent instances such as MAPS Unit 2 at 5:23 Hrs

on 06th

May 2014 it was very much essential for reviewing / re-tuning of PSS of all

the major generators in the region. It was requested that a suitable action plan be

evolved in this regard and the services of experts be availed if required. In the

Meeting taken by Secretary (Power) on 11th

March 2014 (copy enclosed as

Annexure-XX) to discuss the Task Force Report, it can be seen that CTU had been

entrusted the responsibility of PSS tuning.

17. 2 It had also been desired that exercises such as analysis of grid conditions, factors

affecting grid operation etc be done by a dedicated system study group in each

utility and load dispatch centres. Details of the same could be communicated to the

respective RPC.

17.3 In the Meeting, CTU informed that they did not have the required expertise to

take up PSS tuning works.

17.4 MS I/c, SRPC noted that PSS tuning works had been entrusted to CTU by MoP

and requested CTU to take up the matter appropriately.

18. IMPLEMENTATION OF ENQUIRYCOMMITTEE RECOMMENDATIONS

18.1 Implementation of measures to prevent Grid Disturbance

(A) Third party Protection Audit

In the 24th


Chairperson, SRPC vide letter dated 10th

December 2013

addressed to Secretary (Power), Government of India had

requested for 100% funding from PSDF for renovation and

up gradation works of protection system in Southern Region.

Hon’ble CERC had pronounced Orders in respect of the

Petition No. 146/MP/2013 with I.A 36/2013, dated 20th

February 2014. Following are the salient points for kind

compliance:

Respondents are to implement the works as

mentioned in Phase-I and Phase-II by 1.5.2014

and 1.9.2014 respectively.

SRPC has been directed to coordinate the

protection setting issue and submit a report

regarding implementation of Phase-I activities by

1.6.2014.


SRPC had been further directed to submit

bimonthly status report for works mentioned in

Phase-II to the Commission.

In OCC Meetings, SRLDC pointed out that in the

compliance report submitted by the states for CERC

compliance, constituents had indicated status as ‘Tendering

in Process’ / ‘Items to be procured’ etc., This nature of

indication of status does not show any timeline / type of

tendering / important or urgency attached by the

constituents/commitment of constituents for compliance.

Therefore, all the constituents were requested to indicate the

break-up details of individual activities involved in a

particular recommendation with target time schedule of

completion.

Hon’ble CERC had already notified the (Power System Development

Fund) Regulations, 2014. Appraisal Committee under chairmanship of

Chairperson, CEA and Monitoring Committee headed by Secretary,

MoP had already been constituted. NLDC has been designated as Nodal

agency for PSDF. All states were requested to kindly prepare the DPR

for R&U as above and resubmit the same to NLDC i.e. Nodal Agency

with a copy to GM Division.

18.1.1 In the Meeting the following was noted:

KSEB had submitted the revised DPR to NLDC (Nodal Agency for PSDF).

Appraisal Committee had approved the DPR of Kerala.

It was requested that other constituents may also submit the DPRs to NLDC

to avail funding from PSDF. The nomination of Nodal Officers as requested

by NLDC could also please be expedited.

As regards Protection Audit, SRLDC/SRPC Secretariat requested all the

concerned utilities to expedite pending works and furnish the status update

to SRLDC/SRPC as per agreed time schedules. Hon’ble CERC was needed

to be approached for time extension, if required. It was noted that KSEB had

already approached Hon’ble CERC with a petition in this regard. It was also

agreed that a Meeting would be convened to assess the progress of

implementation of Phase I and Phase II activities. The report in this regard

had to be submitted to Hon’ble CERC.


(B) Reactive Power Planning

In the 23rd

Meeting of SRPC, it had been agreed that Utilities

would furnish the schemes relating to Reactive Power

Planning including at distribution level within one month

indicating also the time schedules for implementation.

Progress of these schemes would be monitored in the SRPC

forum. Request for funding through PSDF could be sought at

a later date.

In the Meeting, constituents were requested to please furnish the

schemes at the earliest, wherever due.

(C) Ensuring proper functioning of UFRs and df/dt relays

In the Second Meeting of NPC, it had been decided that all

SLDCs and RLDCs would upload the details of feeders to be

tripped through the UFRs and the expected load relief at

different frequency levels in their respective States/Regions

on operations of UFRs. It had been also decided that RPCs

would submit inspection report of healthiness of UFR and

df/dt regularly on a quarterly basis to the NPC Secretariat.

18.2 Reporting the Status of implementation of the recommendations of the

Enquiry Committee

Status as on last day of the month to be forwarded by 3rd

day of the following

month, and that as on 15th

of the month to be forwarded by 17th

of the month. All

the constituents were requested to furnish timely status updates on the status of

implementation.

18.3 Review of Zone -3 Philosophy

The issue had been deliberated in Protection Sub-Committee Meeting held on 21st

November 2013 and settings for critical 400 kV lines had been finalized for

implementation.

18.4 Ring Fencing of Load Dispatch Centers (LDCs)

18.4.1 The status report on this was to be submitted every month to the NPC Secretariat.

18.4.2 In the 24th

Meeting of SRPC, it had been noted that Chairperson, SRPC vide letter

dated 11th

December 2013 addressed to Chairperson, CEA had conveyed the

opinion expressed by the constituents in the 23rd

SRPC Meeting with regard to

ring fencing of Load Despatch Centres.

18.4.3 In the Meeting it was noted that there was no change in the status.

18.4.4 ED, SRLDC stated that the staff needed to be strengthened in all the SLDCs.


18.5 Utilization of LDC development fund for System Operators Training


July 2014 (refer Annexure-VI) had stated as

per Orders of Hon’ble CERC in respect of Petition No.117/MP/2013, training

programmes could be conducted at NPTI and expenditure for the same could be

met from the LDC development fund. It has been stated that confirmation

whether cost for system operators training programme can be utilized from LDC

development fund be given so that SLDC could sponsor Officers for participation

in NPTI courses.

18.5.2 In the Meeting, ED, SRLDC informed that a letter had already been addressed to all

the constituents in this regard

19. REVIEW OF PERFORMANCE OF ULDC SCHEME

19.1 In the 23rd

& 24th

Meetings of SRPC, the following had been noted:

SRLDC had informed that in respect of pending data from

Talcher, all links for ICCP configuration at ERLDC had been

utilized. PGCIL needed to explore provision of hardware splitter at

Talcher.

In accordance with RoP in respect of Petition No. 56/SM/2013,

SRPC vide letter dated 9th

December 2013 had furnished status

update to Hon’ble CERC with copy to utilities for necessary

action.

19.2 In order dated 19th

December 2013 on Suo-Moto petition 56/SM/2013, Hon’ble

Commission had directed all the utilities to provide the required telemetry within

six months of this order. Progress of compliance in this regard by various utilities

wart. the report submitted on 25.09.2013 was compiled and submitted to Hon’ble

Commission in March 2014.

19.3 In the 96th

Meeting of OCC held on11th

June 2014 the following had been noted:

SRLDC had presented the status of data, voice and internet

communication and pending field inputs.

It was stated that the Stand by data channel and Voice Communication

from NTECL Vallur to SRLDC was frequently going out of order.

NTECL Vallur had informed that they had procured four converter

cards and handed over to PGCIL for installation. PGCIL/NTECL were

requested to complete the pending works at the earliest.

Standby data channel from 400 kV SS (SR-1 and SR-2) was to be

made through. Talcher Stage II data was still to be configured. PGCIL

had informed that DCPC for Talcher Stage II data had been installed


and extended to SRLDC end. Only integration works at SRLDC end

were pending.

Non availability of data in real time from NLC Stage II was yet to be

rectified. Reliable and dedicated internet communication was to be

ensured by all the users.

SCADA data was not being updated from Puducherry due to Front

End Processor fault at Puducherry Control Centre. Puducherry

informed that procurement of the equipment was under progress.

19.4 Subsequently Hon’ble CERC had issued show cause notice under section 142 to

constituents in its ROP in respect of Suo motu Petition No. 007/SM/2014 listed

for hearing on 22nd

May 2014.

19.5 In the Meeting the following was noted:

SRLDC presented the status of data, voice and internet communication

and pending field inputs. Details are enclosed as Annexure-XXI. It was

requested that other pending points be completed.

SRLDC informed that data for Talcher-II had been extended up to

SRLDC and integration was to be done with the new SCADA system.

SR-II PGCIL informed that the 8 points ( Talcher) pertaining to SR-II

had also been extended to SRLDC.

NTECL informed the Standby data channel and Voice Communication

would be rectified within two days.

Hot line between APSLDC and SRLDC was to be established.

It was noted with appreciation that Southern Region had the minimum

number of pending points as compared to other regions in the country.

20. NON-PAYMENT OF TRANSFORMER CHARGES TO TN BYSOUTHERN

REGION CONSTITUENTS AND PENDING ARREARS PAYMENT

BETWEEN BENEFICIARY STATES IN SR

20.1 In the 24th


TN had agreed to make payments for the undisputed amounts as per

the Minutes of the Meeting held with KPTCL. Similarly, they

requested that undisputed payments, due to TN be released. They

also informed that all relevant documents as per the MoM had been

furnished to KPTCL.

Regarding transformer charges, KPTCL had informed that 3

ESCOMS had paid while TANTRANSCO informed that payment

was being received from one ESCOM only. KPTCL had requested

that TANTRANSCO may coordinate with PCKL in this regard.


APTRANSCO had informed that they had settled the issue

regarding monetary compensation and due payments had been

released to TANTRANSCO.

On a request, APTRANSCO had informed that they would consider

the issue regarding monetary compensation payment to KSEB

TANTRANSCO had requested APTRANSCO and KPTCL to

finalize a convenient date for a Meeting at Chennai to settle the long

pending issue regarding frequency linked penalty/incentive.

20.2 Subsequently, TANTRANSCO vide letter dated 17th

June 2014 (Annexure-XXII)

had informed that they had received payment of Rs.1,59,07,117/- made by all five

ESCOMs of Karnataka towards transformer charges.


July 2014 (refer Annexure-VI) had stated that

an amount of Rs.26.50 Crore has to be paid by Karnataka to TN towards monetary

compensation and payment for the period between December 1998 to March 2001.

As requested by KPTCL, the entire set of documents had been made available to

KPTCL and PCKL. Regarding Frequency Linked Penalty/ Incentive Scheme for

overdrawal/ underdrawal of shares, TANTRANSCO had stated that APTRANSCO

and KPTCL may give suitable date for their visit to Chennai. It had also been stated

that the Nodal Agency SRLDC has to furnish the invoices sought by KPTCL on the

above issue


July 2014 (refer Annexure-VIII) had stated that an

amount of about Rs.4.77 crores is net receivable to KSEB from PCKL. An amount

of Rs.11.58 crores with interest is to be included as payable from KPTCL as

charges towards frequency linked penalty for over drawal during the period April

1994 to May 1997. It is also stated that an amount of Rs.14.5 crores is receivable

from AP towards compensation for frequency linked under drawal/over drawal. An

amount of around Rs.1.46 crores is receivable towards sale of KSEB power for

October 1992. KSEB had admitted APs claim of Rs.35,58,381/- payable by KSEB

towards transmission and wheeling charges for the month of March 2013.

20.5 In the Meeting 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

20.6 APTRANSCO stated that it had already rejected the claims in respect of frequency

linked penalty/incentive scheme along with valid reasons. It had also been decided


that this issue would be resolved bilaterally and was not to be included as agenda in

SRPC meeting.

20.7 KSEB/TANTRANSCO stated that since this issue was not getting resolved

bilaterally, it had been brought to SRPC forum.

20.8 TANTRANSCO stated that SRLDC was the designated agency for frequency

linked penalty/incentive scheme and hence it should provide necessary data for

settling this issue.

20.9 ED, SRLDC 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.

20.10 Chairperson TCC suggested that a separate Meeting could be convened and

SRLDC may provide necessary guidance in this regard.

21. OUTSTANDING DUES BETWEEN WR & SR

21.1 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 fifth Meeting in this regard was held

on 21stMay 2014 at Mumbai, where in it was agreed that by end of June 2014

MSEDCL & MPPMCL would furnish the reconciled statements to SR constituents.

21.2 PTC had deposited an amount of Rs.3,70,85,091/- with Corporate Office

POWERGRID during the year 2002 (Annexure-XXIII). Out of Rs.3,70,85,091/-

Rs.1,80,89,611/- is pertaining to SR beneficiary States/UT and the same was to be

adjusted towards transmission charges payable by SR beneficiary States in the ratio

of transmission charges paid by them for the month of August & September 2002.

WRTS had confirmed that the entire amount deposited by PTC had been fully

adjusted towards WR transmission charges payable by WR Constituents. PGCIL

has therefore to adjust the amount pertaining to SR beneficiary States/UT

appropriately.


July 2014 (refer Annexure-VI) had stated that

as agreed in the Meeting held at Mumbai, Maharashtra and MP would furnish the

reconciliation statement to the SR constituents by end of June 2014.



July 2014 (refer Annexure-VIII) had furnished the

details of outstanding principal amount pending for payment from WR constituents

for the period prior to January 2003.

21.5 In the Meeting, SRTS-II, PGCIL informed that WRTS had taken up the matter with

WR constituents and the amount due to SR constituents would be passed on.

21.6 After deliberations, it was agreed that a Meeting could be held between WR and SR

to settle the issue.

22. GRID OPERATION

22.1 Grid events/highlights during March 2014

Southern Region met demand of 36,985 MW on 24.03.2014 which

was maximum till date.

Sothern Region met a day energy consumption of 856.67 MU on

26.03.2014

Andhra Pradesh met demand of 13,621 MW on 23.03.2014 which

was maximum till date.

Andhra Pradesh met a day energy consumption of 293.84 MU on

22.03.2014 which was maximum till date.

Kerala met demand of 3,588 MW on 18.03.2014 which was

maximum till date.

400 kV Chittoor-Tiruvalam DC quad line and new 400 kV

Tiruvalam Sub Station along with 1x 63 MVAR bus reactor at

Tiruvalam Substation and associated bays and equipment at

Tiruvalam and Chittoor under supplementary Transmission system

associated with Vallur TPS have been put under Commercial

operation w.e.f 01.04.2014 by PGCIL.

Transmission System associated with Krishnapattanam UMPP

Part C1 have been put under commercial operation w.e.f

01.04.2014 by PGCIL:

LILO of 400 kV Nagarjunasagar-Gooty SC line at

Kurnool(new) Substation along with associated bays

and equipment.

400 kV Kurnool (new) – Kurnool (APTRANSCO)

DC quad line along with associated bays and

equipments.

2 x 1500 MVA Transformers at 400kV Kurnool SS

along with associated bays and equipments.

1 x 240 MVAR bus reactor at Kurnool (new) SS

along with associated bays and equipments.

OPGW communication links along with associated

communication equipment under the project establishment of fiber


optic communication system for central sector stations project of

Southern Region have been put under CoD w.e.f 01.04.2014 by

PGCIL:

LILO of Bangalore-Salem to Hosur (25.52 kM)

LILO of Madurai- Trichy at Karaikudi (48.87 kM)

Tirunelveli-Kudankualm(72.71 kM)

Chittor- Tiruvalam(21.02 kM)

LILO of Kolar- Sriperumbudur to Tiruvalam(12.07

kM)

Sriperumbudur- Chittoor LILO(95.82 kM)

765/400 kV, 1500 MVA Transformer Bank (2nd ) at Nellore

Pooling Station along with associated bays and equipment was

declared COD from 01.03.2014 by SRTS I, PGCIL.

765 kV, 240 MVAR Bus Reactor at Nellore Pooling Station along

with associated Bay and Equipments was declared COD from

01.03.2014 by SRTS I, PGCIL.

220/132 kV, 2 x 100 MVA Transformer at Sadasivpet was

commissioned by APTRANSCO on 29.03.2014.

LILO line from 220 kV Gachibowli –Tandur to 400 kV

Yeddumailaram of 20ckm was charged by APTRANSCO on

14.03.2014.

220 kV Shadnagar to Yeddumailaram line was charged by

APTRANSCO on 07.03.2014.

220 kV DC Line from 400 kV Yeddumailaram to 220kV

Sadasivpet of 74 ckm was commissioned by APTRANSCO on

29.03.2014.

Wind mills of capacity 17.7 MW had been added in Tamil Nadu.

22.2 Grid events/highlights during April 2014

Karnataka met demand of 9,718 MW on 07.04.2014 which was

maximum till date.

Karnataka met a day energy consumption of 211.22 MU on


Kerala met a day energy consumption of 70.13 MU on 03.04.2014

which was maximum till date.

Puducherry met a day energy consumption of 7.43 MU on




22.3 Grid events/highlights during May 2014


LILO of one ckt of 400 kV Neyveli-Trichy DC line at Nagapattinam

Pooling station under common transmission scheme associated with

ISGS projects in Nagapattinam/Cuddalore area of Tamil Nadu was

ready for the intended use w.e.f. 03.05.2014.

22.4 Grid events/highlights during June 2014

The state of Andhra Pradesh had been bifurcated into two new states

namely Andhra Pradesh and Telangana w.e.f 02.06.2014.

Tamil Nadu daily energy consumption of 294 MU on 20.06.2014

which is maximum till date.

Tamil Nadu met a demand of 13,771 MW on 24.06.2014 which is

maximum till date.

Wind mills of capacity 82.54 MW had been added in Tamil Nadu

during the month of June 2014.

765 kV Kurnool –Raichur 2nd

ckt along with associated bays and

equipments at Kurnool and Raichur SS under ‘Transmission System

associated with ISGS Krishnapattnam’ had been put under

Commercial Operation wef 00:00 hrs of 21st June 2014.

22.5 Installation of Shunt Capacitors

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

2014-15 is furnished in the Table below:

(Figures in MVAR)

State Requirement

for 2014-15

Installed during the year

2014-15 (till 30th

June2014)

Andhra Pradesh 26.20 0.00

Karnataka 56.31 0.00

Kerala 10.00 0.00

Tamil Nadu 122.40 0.00

It was requested that installation of required capacitors works be completed

within six months.

23. DEMAND VARIATION (Peak Vs Off-peak)

23.1 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 March 2014 to June 2014:


Month Minimum to Maximum Demand Variation %

Andhra

Pradesh Karnataka Kerala

Tamil

Nadu Puducherry

Southern

Region

March 2014

Highest 28.68 32.02 41.07 23.53 41.66 19.54

Date 4th

(Tue) 27th

(Thu) 3rd

(Mon) 10th

(Mon) 5th

(Wed) 10th

(Mon)

Lowest 13.70 10.45 31.47 6.42 18.35 8.45

Date 27th

(Thu) 28th

(Fri) 1st(Sat) 22

nd(Sat) 30

th (Sun) 29

th (Sat)

Average 19.02 19.88 35.30 15.97 32.72 13.23

April 2014

Highest 17.74 31.73 43.13 20.24 42.46 15.78

Date 5th

(Sat) 17th

(Thu) 9th

(Wed) 25th

(Fri) 24th

(Thu) 28th

(Mon)

Lowest 8.98 14.12 17.98 8.78 15.14 6.63

Date 29th

(Tue) 4th

(Fri) 30th

(Wed) 2nd

(Wed) 20th

(Sun) 17th

(Thu)

Average 13.45 20.36 32.43 12.44 26.43 10.87

May 2014

Highest 30.98 45.38 47.55 22.74 63.32 27.26

Date 27th

(Tue) 9th

(Fri) 9th

(Fri) 10th

(Sat) 15th

(Thu) 9th

(Fri)

Lowest 7.53 17.32 19.60 10.14 16.29 8.89

Date 16th

(Fri) 25th

(Sun) 28th

(Wed) 11th

(Sun) 25th

(Sun) 18th

(Sun)

Average 17.10 25.82 32.35 15.95 29.25 14.94

June

2014

Minimum to Maximum Demand Variation %

Andhra

Pradesh Karnataka Kerala

Tamil

Nadu Telangana Puducherry

Southern

Region

Highest 24.78 49.21 39.82 32.19 36.46 53.56 20.67

Date 13th

(Fri) 3rd

(Tue) 13th

(Fri) 9th

(Mon) 18th

(Wed) 12th

(Thu) 9th

(Sun)

Lowest 9.75 12.78 22.23 10.44 5.02 12.49 9.50

Date 8th

(Sun) 28th

(Sat) 7th

(Sat) 1st (Sun) 29

th (Sun) 29

th (Sun) 26

th (Thu)

Average 16.41 24.61 34.19 18.68 11.94 23.60 13.76

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

values.

23.2 Constituents were kindly requested to implement suitable DSM measures and also

share information with other constituents for mutual benefit.


24. FREQUENCY OF OPERATION OF SOUTHERN GRID

24.1 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

March 2014 0.01 0.48 19.80 35.36 18.48 23.46 2.41 53.84 49.98

April 2014 0.01 1.83 34.20 36.56 13.94 12.85 0.61 50.50 49.94

May 2014 0.01 1.45 25.42 34.14 17.40 19.66 1.92 51.54 49.97

June 2014 0.25 5.99 34.32 29.95 13.99 14.36 1.04 43.94 49.92

24.2 During the period under review, caution / violation messages (Annexure-XXIV)

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

frequency by some constituents is being regularly deliberated in the OCC forum.

Utilities are requested to kindly adhere to Regulations in this regard.

24.3 In the Meeting on 6th

May 2014 taken by Secretary (Power) to discuss

preparedness of the power sector to tackle effects of subnormal monsoon, it had

been agreed that reservoir based hydro stations would conserve water and utilize

the same optimally with immediate effect so that stored water may be utilized in

the event of deficient monsoon.

25. TRIPPING DETAILS

25.1 Tripping Details/Reports

25.1.1 The following is contained in the RoP of Hon’ble CERC in respect of Petition

No. 146/MP/2013 with IA 36/2013(date of hearing 19th

December2013):

“7 The Commission also noted that the petitioner raised the issue of

Non-compliance of the Regulation 5.2(r) of the Grid Code which

mandated all users to report the disturbance/fault to RLDCs within

24 hours of occurrence. The Commission directed the Petitioner to

submit the instances of non-compliance by SLDC/Users by

10.01.2014.”

25.1.2 Subsequently Para 29 of Order dated 20th

February 2014 in respect of Petition

No. 146/MP/2013 of Hon’ble CERC contains the following:

“29. …... We administer a strong warning to the respondents to

take all possible measures permissible under the Act and the


Grid Code to provide data /information to RLDC and RPC for

maintaining reliability and security of the grid. We also make it

clear that failure in this regard will amount to non-compliance

of the directions of this Commission and render the constituent

liable for proceedings under Section 142 of the Electricity Act,

2003 and other relevant provisions. We also direct the petitioner

and SRPC to coordinate and monitor the progress and

compliance of Commission's directions and ensure compliance

of Regulations 5.2 (r) of the Grid Code and report instances of

non-compliance to the Commission...”

25.1.3 In the OCC/Protection Sub Committee Meetings, SRLDC had expressed serious

concern over the fact that information regarding tripping details with relay

indications was awaited from many of the constituents. It had been stated that

entities needed to furnish the preliminary report on ‘events’ in compliance of

IEGC Regulation, 5.9.6(a). Detailed report along with necessary information as

mandated by IEGC should be followed. CEA Regulations mandate furnishing of

the reports within 24 hrs. It was also a matter of concern that certain events had

not been reported at all to SRLDC.

25.1.4 In the Meeting, SRLDC presented the status of tripping details being furnished by

the constituents (Annexure-XXV)

25.1.5 Chairperson TCC said that the tripping details needed to be communicated to

SRLDC/SLDCs in a timely manner to analyze the incidents.

25.1.6 Constituents were requested to furnish the tripping details within the prescribed

time limits.

26. OPERATION OF TALCHER-KOLAR HVDC TRANSMISSIONSYSTEM IN

GROUNDRETURN MODE

26.1 In various forums it had been noted that the flow needed to be restricted to 150

MW in GRM. Till 24th


KPTCL had expressed that the safety of the equipment was of utmost

importance to them. Neutral current beyond the permissible limits

could not be allowed under any circumstances.

PGCIL in consultation with CEA had subsequently appointed

International Consultants with the approved Terms of Reference.

A Special Meeting of TCC with the International Consultants for

Review of Ground Return Mode Operation of Talcher-Kolar HVDC

Link was held on 9th

May 2012 at Bangalore.


Copy of the Report prepared by the Consultant Group forwarded by

PGCIL was circulated to the Members. As agreed in the 19th

SRPC

Meeting held on 1st June 2012, the matter was to be discussed

bilaterally between KPTCL & PGCIL.

KPTCL had sought opinion of their consultant (M/s PRDC) on the

report furnished by PGCIL. It was also desired that after the

finalization of the issue between PGCIL and KPTCL, the outcome

would be deliberated in the OCC meeting before putting up to

TCC/SRPC. PGCIL had also sought the status of measurement as

recommended by the International Consultants.

KPTCL had informed that PRDC was scheduled to take third set of

readings during April-May 2014.

26.2 In the Meeting, Director (Transmission), KPTCL informed that the next set of

readings could be taken in September 2014.

27. PHYSICAL AND CYBER SECURITY/ CRISISMANAGEMENT PLAN/

BLACKSTART PROCEDURES

27.1 Physical and Cyber Security

27.1.1 Status update on Crisis Management Plan (C&DMP) of Power Sector is to be

furnished quarterly. 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 was to be furnished to Chief Engineer, DMLF, CEA, Sewa

Bhavan, New Delhi-66. Copy of the report was to be sent to SRPC

Secretariat ([email protected] and [email protected]). Practices

being followed in respect of Cyber Security/Physical Security/CMP/Mock

Drills w.r.t. Black Start were also required to be communicated

27.1.2 CEA, vide letter dated 26.11.2013 had enclosed MoP letter dated 21.11.2013

regarding Security of power installations and status. It is therefore requested

that the following information in this regard may please be furnished to

Member (GO & D), CEA, New Delhi for onward communication to MoP

with a copy to this office:

Standard Security guidelines for power installations and the status

of implementation including Cyber Security.

Systematic up gradation and modernization of security systems

and procedures.

Coordination and liaison with local police and intelligence units.

27.1.3 The constituents were requested to furnish timely information in this regard.




27.2 Black Start Procedure

Issue regarding Mock drill on Black Start Procedure was being followed up in the

monthly Meetings of the OCC.

28. MODIFICATIONS IN OPGW LINKS UNDER FIBRE EXPANSION

PROJECT OF SR

28.1 PGCIL vide letter dated 11th

July 2014 (Annexure-XXVI) had been stated that

subsequent to approval of the modified fibre optic network in the 24th

SRPC

Meeting, KPTCL and Puducherry Electricity Department have requested for

changes in the routing of the fibre network.

28.2 TCC recommended for the following changes in the routing of fibre network for

approval by SRPC:

OPGW on Hoody – HSR & Hoody –HAL in place of Hoody – ITPL

OPGW on Neyveli – Bahour instead of Neyveli – Villianur for having dual

path for Bahour station.

29. REPLACEMENT OF PRIMARY MULTIPLEXER EQUIPMENTS

INSTALLED UNDER SR-ULDC PROJECT

29.1 PGCIL vide letter dated 11th

July 2014 (refer Annexure-XXVI) had been stated

that primary multiplexer system has been supplied and installed under SR-ULDC

project for data and speech applications. The multiplexer of Alcatel make had been

in operation for the past 14 years. However, due to technical obsolescence it has

been proposed to replace the multiplexer equipment. The estimated cost of the

equipment has been stated to be around Rs.5.75 crores.

29.2 TCC recommended replacement of multiplexer equipment installed under SR-

ULDC Project for approval by SRPC.

30. DIFFERENCE IN COMPUTATION OF CAPACITY CHARGES OF NTPC

STATIONS AS PER NEW CERC REGULATIONS (2014-19)


July 2014 (refer Annexure-VIII) reference had been

invited 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.

30.2 In the Meeting, it was noted that the issue would be first discussed in the

Commercial Sub-Committee.

31. ARBITRARY CURTAILMENT OF STOA AND DENIAL OF URS


July 2014 (refer Annexure-VIII) had been stated that

instances of arbitrary denial/unwarranted curtailment of STOA and URS power by

SRLDC is continued in real time even under reduced line flow across S1-S2 seam.

A few typical instances of arbitrary denial by SRLDC have been cited. These

relate to instances that had occurred on 25th

June 2014, 18th

June 2014, 9th

June

2014 and 8th

June 2014.

31.2 In the Meeting, it was noted that the issue was under consideration of Hon’ble

CERC.

32. PREPAREDNESS FOR BAD MONSOON


July 2014 (refer Annexure-VIII) had been stated that

in view of forecast of bad monsoon, KSEB Ltd. has estimated a shortage of

approximately 2,000 MU in inflow. KSEB Ltd. had already entered into PPA for

purchase of 1,600 MW of power on MTOA/LTA basis. However, only 3 MW has

been approved from June 2014. Power arranged in short term contract is not

permitted by SRLDC on account of apprehended transmission constraints and

fixing unrealistic reliability margins. This ultimately results in under utilization of

transmission and generation assets in the country. In order to meet the power

requirement in this scenario, certain measures have been proposed for discussion in

the Meeting.

32.2 In the Meeting, KSEB requested to consider the following proposal:

Additional power transfer of 500 MW in Talcher - Kolar HVDC poles in

enhanced mode.

Enhancement of S1-S2 ATC for transfer of power by considering the

generation at Kudankulam and the SPS scheme.

TRM could be avoided to ensure maximum power transfer.


32.3 ED, SRLDC informed that the enhanced mode was already being utilized to control

power flow on 765 KV Raichur-Sholapur link.

33. UTILIZATION OF EXISTING ROW OF 66KV KUTHUMUNDA –

UPPATTY FEEDER


July 2014 (refer Annexure-VIII) had been suggested

that feasibility for utilizing ROW of erstwhile 66 kV feeder from Kuthumunda to

Uppatty in Tamil Nadu (lying unutilized for past several years) may be explored

for construction of 220 kV link to Tamil Nadu.

33.2 In the Meeting, TANTRANSCO informed that they were in the process of

upgrading all the existing 66 kV lines to 110 kV. It was not possible to use the

existing RoW of 66 kV Kuthumunda–Uppatty line for construction of 220 kV

link,

33.3 After deliberation, it was agreed that the issue would be discussed bilaterally

between KSEB & TANTRANSCO.

34. PROGRESS OF VARIOUS TRANSMISSION AND GENERATING

CAPACITY WORKS

The Progress of transmission and generating capacity works is furnished at

Annexure-XXVII.

TCC noted the following:

35. START UP POWER DRAWAL BY IL&FS TAMIL NADU POWER

COMPANY LIMITED

35.1 IL&FS Tamil Nadu Power Company Ltd. (ITPCL) is establishing 2x 600 MW

generation project at Cuddalore in Tamil Nadu. As per approved scheme,

evacuation of power from ITPCL would be through PGCIL Nagapattinam

Pooling Station connected through dedicated 400 kV D/C line from ITPCL to

Nagapattinam Pooling Station.

35.2 In its 24th

Meeting held on 15th

March 2014,SRPC had approved LILO of one

circuit of Neyveli – Trichy line at Nagapattinam PS for the purpose of drawal of

startup power by ITPCL.


35.3 In the 24th

Meeting of Commercial Sub Committee of SRPC held on 13th

May

2014, the following had been noted:

PGCIL had informed that LILO of one circuit of 400kV Neyveli –

Trichy line at Nagapattinam PS was ready and deemed to have

been commissioned with effect from 03rd

May 2014. 400kV D/C

line from ITPCL switch yard to Nagapattinam Pooling Station was

not ready.

SRLDC had stated that as per Regulations, Neyveli and Trichy ends

are the ISTS touch points of ITPCL. Hence drawal or injection is to

be accounted with SEMs at NLC and Trichy end. Any deviation

may have to be brought to the notice of Hon’ble CERC. SRLDC

would not carry out any modifications w.r.t apportionment of losses

etc.

After deliberations, it had been agreed by Commercial Sub-

Committee (except SRLDC) that as an interim measure, the energy

drawal by ITPCL be computed based on the SEMs at ITPCL end.

Further the drawal would be increased (post facto) by the regional

loss percentage (used for scheduling for the week) during

accounting by SRPC Secretariat. This would be an interim measure

till commissioning of Nagapattinam PS.

36. UDUMALPET &GAZUWAKA ICTs - STATUS OF CERC PETITION

36.1 PGCIL vide Notification dated 23rd

March 2010 had notified that Udumalpet ICT-I

(315MVA) was not on commercial operation with effect from 23.03.2010 and

charges would not be claimed till further communication. The ICT was put back on

commercial operation from 01.07.2010. In respect of Gazuwaka ICT also similar

notification had been issued by PGCIL. Gazuwaka ICT was out of commercial

operation from 01.05.2009 to 30.06.2009.

36.2 In the 13th

Meeting of SRPC held on 11th

May 2010, PGCIL had informed that they

would approach CERC with petition. For the period from 23rd

to 31stMarch 2010 the

outage of Udumalpet ICT would be to PGCIL account. From 1stApril 2010, the

element would be taken out from the availability calculations and subsequently

CERC order on the petition would be followed.

36.3 The issue had been discussed in the Special Meeting held on 04th

April 2014 where

in PGCIL representative had informed that they had taken up the issue with their

Commercial Wing and they would revert back.

36.4 The issue was further discussed in the 24th

Meeting of Commercial Sub-Committee

held on 13th

May 2014,wherein PGCIL had informed that tariff adjustment on


account of denotification of the subject ICT's for the part of the 2009-14 tariff block

would be carried out in the truing up petition for 2009-14 to be filed before CERC.

37. SCHEDULING POWER TO TELANGANA & ANDHRA PRADESH FROM

SHARED STATIONS, IPPs AND SIMHADRI STPS STAGE-I

37.1 In the Special Meeting of TCC held on 8th

May 2004, TCC had agreed that the

following issues raised by APTRANSCO would be further discussed in the

Commercial Sub Committee Meeting scheduled on 13th

May 2014, wherein the

decision would be taken on the matter:

Issue No.1: APGENCO stations will have PPAs of Discoms from

both States. Because of this, Genco will become inter-state

generators. There are Inter-State Lines between Telangana and AP

owned and operated by Telangana and AP State. There will be net

power transfer either from Telangana to AP or vice versa every

month. Do importing state have to pay charges for such net power

transfer to PGCIL? Or to Other State? And how much?

Issue No.2: Each Discom will be getting power from Genco station

of other state. Will Discom of one state pay Transmission charges &

losses to other State Transco? For example CPDCL (TG State) will

draw power from VTPS (AP State). Will CPDCL pay transmission

charges and losses to AP Transco?

Issue No.3: Is it possible present Energy Billing Centre of

APTRANSCO to finalize the energy transactions between both the

States DISCOMs in every month and also for certification of energy

from various generators i.e. presently being done by SRPC for SR

States against utilization of power from Central Generating Stations

and also inter-state open access transactions?

Issue No.4: Who will work out the losses separately to both the

States for utilization/scheduling of power from the Generating

Stations?

Issue No.5: In which manner, Simhadri Stage-I, UI charges would

be segregated to both the States and also whether Simhadri Stage-I

scheduling would be done by SRLDC or APSLDC?

37.2 In the 24th

Meeting of Commercial Sub-Committee of SRPC held on 13th

May

2014, APPCC had informed that CMD, APTRANSCO had directed him to

convey the following decision on the issues:

Methodology being followed in Northern Region in respect of shared

generators could be similarly adopted in respect of Net Power transfer

from Telangana to AP. As such, transmission charges to PGCIL would

not be payable for the Power Transfer from Telangana to AP or vice

versa


State Losses & Transmission Charges would be decided mutually.

Separate charges would not be applicable. (only net schedule being

considered by SRLDC).Existing APERC approved loss percentage

would be used for scheduling of power.

Power from Central Generating Stations as well as STOA transactions

would be scheduled by SRLDC and the details in respect of AP and

Telangana would be shown in the Monthly REA issued by SRPC

Secretariat. Energy Billing Centre would issue Account for the energy

scheduled from respective state generating stations.

Simhadri STPS Stage-I station would be scheduled by APSLDC.

37.2.1 SRLDC had stated that as per PoC Regulations, PoC charges and Losses are

to be applied on four components viz charges for Injection from

AP, withdrawal charges for Telangana’s share and vice-a-versa. SRPC

Secretariat may apprise the issue and request to hold a Validation

Committee meeting on an urgent basis. Matter could be put up to the

Validation Committee for suitable directions. AP SLDC had agreed to

schedule and dispatches Simhadri STPS Stage-I under its control area and

schedule the shares to Telangana. As per clause 6.4.3.of IEGC, which states

that there may be exceptions with respect to above provisions, for reasons of

operational expediency, subject to approval of CERC.

37.2.2 After deliberations, the following had been agreed:

Matter regarding sharing of transmission charges and losses would be

referred to Validation Committee requesting a meeting on urgent

basis.

However, pending decision of Validation Committee, CMD,

APTRANSCO decisions as mentioned above would be followed.

APSLDC would approach CERC for approval for scheduling and

accounting of Simhadri STPS Stage-I by APSLDC.

37.3 The 2nd

Meeting of the Validation Committee for the year 2014-15 (2nd Quarter,

July - September 2014) for implementation of CERC (Sharing of Inter-State

Transmission Charges and Losses) Regulations 2010 was held on 4th

June, 2014,

wherein the issue was discussed. (relevant extract of Minutes enclosed as

Annexure -XXVIII)

38. COLLECTION OF DATA REGARDING POWER SUPPLY TO RURAL

AREAS

CEA had informed that in the Meeting held in MoP on 09.04.2014, it had been

decided to collect the data from DISCOMs in a simplified format. SRPC vide


letter dated 11.04.2014 enclosing CEA letter had requested that the data in this

regard in the format may be communicated to SRPC Secretariat at the following

E-mail addresses:

[email protected]

[email protected]

Data is to be communicated by first week of the month in respect of the previous

month. Constituents were kindly requested to furnish the validated data in a

timely manner.

39. SNAPPING OF POWER CONDUCTORS OVER TRACTION LINES-

SOTHERN RAILWAY

39.1 Southern Railways had raised the issue of snapping of earth conductor in KSEB

system between Kazhakuttam-Kochuveli stations on 25th

May 2014 and snapping

of TANTRANSCO 230 kV NCTPS-ETPS phase conductor crossing Railway

traction lines of all four tracks between Ennore-Attippattu on 18th

April 2014 at

about 1003 hrs. The matter had been taken up with KSEB and TANTRANSCO at

Chairman level vide letters dated 26.05.2014 and 22.04.2014 respectively.

39.2 Railways were requested to give such type of operational issues in advance for

fruitful deliberations. It was also pointed out that the Railways should allow

restoration of lines at the earliest and commercial matters could be settled

subsequently. For restoration hot line was available between SLDCs and TPCs

which could be utilized for expediting the works. The TRANSCOs were

requested for periodical inspections/timely maintenance of line crossings railway

traction lines. SLDCs were requested to kindly give similar instructions to

DISCOMs.

40. TRANSMISSION LINE PATROLLING PROTOCOLS/ GUIDELINES

In compliance of Orders of Hon’ble CERC in respect of Petition No. 146/MP/2013

with I.A 36/2013, dated 20th

February 2014, Transmission Line Patrolling Protocols

/ Guide Lines had been submitted to Hon’ble CERC vide SRPC letter dated 21st

May 2014. Communication had also been addressed to the constituents for

implementation/necessary action in this regard.


41. DATE & VENUE OF THE NEXT TCC MEETING

It was decided to hold the 25th

Meeting of TCC one day prior to the 26th

Meeting of

SRPC.

42. VOTE OF THANKS

Member Secretary I/c, SRPC thanked the Members and other participants for their

active participation in the deliberations.

Chairperson, TCC thanked all the Members for their cooperation.

******

Documents

दविण ित्र विद्यत सववत · In 1971, the first Thermal power plant at Ennore was started with 60 MW capacity. ... reliable and quality power as per