southern regional power committee - karnataka · corridor due to laying of transmission line and...

Agenda for the 28th TCC & 29thSRPC Meetings to be held on 4th and 5th March 2016

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

2. CONFIRMATION OF THE MINUTES OF 27th TCC & 28th SRPC MEETINGS ................................................ 3

3. GUIDELINES FOR PAYMENT OF COMPENSATION TOWARDS DAMAGES IN REGARD TORIGHT OF WAY

FOR TRANSMISSION LINES ...................................................................................................................... 3

4. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER ENVIRONMENT (PROTECTION)

AMEN DMENT RULES, 2015 .................................................................................................................... 4

5. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY ............................................................... 4

6. IMPLEMENTATION OF SPS FOR CONTINGENCY OF 400 kV NELLORE - NELLORE PS LINES AND

DIFFERENTIAL PROTECTION.................................................................................................................... 5

7. METERING AND ACCOUNTING OF NTPC KUDGI STPP STAGE-I .............................................................. 6

8. STATUS OF GENERATION IN GENERATING STATIONS ............................................................................ 8

9. TTC / ATC ................................................................................................................................................ 9

10. REVIEW OF ULDC / SCADA/COMMUNICATION .................................................................................... 10

11. UPCOMING TRANSMISSIONSYSTEM .................................................................................................... 12

12. UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH TRANSMISSION NETWORK ..... 27

13. FOLLOW UP ACTIONS ON THE RECOMMENDATIONS OF CENTRAL ADVISORY COMMITTEE (CAC) SUB -

COMMITTEE ON CONGESTION IN TRANSMISSION ............................................................................ 28

14. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ........................................................ 29

15. NEW PROJECTS OF STATE SECTOR & IPP .............................................................................................. 30

16. EMERGENCY RESTORATION SYSTEM (ERS) .......................................................................................... 31

17. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR ...................................................... 32

18. ISSUES IN RESPECT OF CONGESTION CHARGES ................................................................................... 35

19. ADDITIONAL SUPPORT THROUGH 110 KV PARASALA – KUZHITURA FEEDER ...................................... 35

20. OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS ............................................... 35

21. SRPC CERTIFICATION TO CLAIM ADDITIONAL RoE ............................................................................... 37

22. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION ...................................................................... 38

23. GRID STUDY COMMITTEE (GSC) (TASK-2) AUDIT PROGRESS DETAILS ................................................. 57

24. ISSUES RELATING TO PSDF FUNDING ................................................................................................... 58

25. AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM .................................................................. 58

26. APPROACH BEING TAKEN BY CTU FOR RESERVING THE TRANSMISSION CAPACITY FOR THE CUSTOMERS

WHO HAVE AVAILED LTA WITHOUT IDENTIFYING BENEFICIARIES ...................................................... 59

27. PENDING REACTIVE CHARGES .............................................................................................................. 60

28. TRANSMISSION CHARGES LIABILITY FOR THE LONG OUTAGE/ SUSTAINED INABILITY TO MAINTAIN THE

APPROVED INJECTION .......................................................................................................................... 60

Agenda for the 28th TCC & 29thSRPC Meetings to be held on 4th and 5th March 2016

29. REIMBURSEMENT OF SRPC EXPENDITURE ........................................................................................... 60

30. GRID OPERATION .................................................................................................................................. 61

31. PROTECTION SYSTEM ANALYSIS GROUP (PSAG-14) MEETING HELD AT MAPS, KALPAKKAM ON

18.12.2015 ............................................................................................................................................ 68

32. THOROUGH REVIEW OF ALL THE DRAWAL POINTS OF STATES FOR DRAWAL COMPUTATIONS ......... 68

33. INCLUSION OF DRAWAL OF MAHE IN REA ........................................................................................... 68

34. SHARING OF TRANSMISSION CHARGES OF TRANSMISSION ASSETS OF NATIONAL IMPORTANCE ..... 69

35. ACCOUNTING METHODOLOGY FOR LKPL STAGE II AND LKPL STAGE III ............................................. 70

36. TPCIL REQUEST TO EXEMPT DEVIATION CHARGES .............................................................................. 70

37. PROLONGED OUTAGE OF 765 KV RAICHUR-SHOLAPUR – 2ND CKT ...................................................... 70

38. AP & TELANGANA SCHEDULING ISSUES OF SHARED PROJECTS & OPERATIONAL ISSUES ................... 71

39. POWER SUPPLY ISSUES AFFECTING METRO SERVICES ......................................................................... 71

40. Outage Coordination through OCC....................................................................................................... 71

41. SCHEDULING OF NTPC RAMAGUNDAM SOLAR POWER PLANT (10 MW) ............................................ 72

42. Assessment of Metering Requirement ................................................................................................. 73

43. IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT SYSTEM FOR SOUTHERN

REGION ................................................................................................................................................. 73

44. STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY RESOURCES INTO THE GRID . 74

45. FURNISHING THE WIND GENERATORS DATA FOR PLEXOS STUDY OF GREENING THE GRID PROJECT 74

46. UPDATE ON 230 KV BHAVINI-KANCHIPURAM ...................................................................................... 74

47. MEMBERSHIP OF NLDC ......................................................................................................................... 75

48. MEMBERSHIP OF COASTAL ENERGEN .................................................................................................. 75

49. ANY OTHER ISSUE WITH THE PERMISSION OF THE CHAIR ................................................................... 75

50. DATE & VENUE OF THE NEXT SRPC MEETING ...................................................................................... 75

Agenda for 28th TCC & 29th SRPC Meeting to be held on 04th and 05th March 2016 Page 3 of 75

SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

AGENDA FOR THE 28th

TCC & 29th

SRPC MEETINGS TO BE HELD ON 4th

AND 5th

MARCH 2016 AT VISHAKHAPATNAM

1. INTRODUCTION

The 28th

Meeting of Technical Co-ordination Committee and 29th

Meeting of Southern

Regional Power Committee (SRPC) would be held on 4th

& 5th

March 2016 respectively

at Vishakhapatnam.

2. CONFIRMATION OF THE MINUTES OF 27th

TCC & 28th

SRPC MEETINGS

Minutes of the 27th TCC Meeting held on 9th October 2015 in Goa were circulated vide

letter dated 18.11.2015. No comments have been received, Minutes may kindly be

confirmed

Minutes of the 28th

SRPC Meeting held on 10th

October 2015 in Goa were circulated

vide letter dated 09.12.2015. No comments have been received, Minutes may kindly be

confirmed.

For Deliberation in SRPC

3. GUIDELINES FOR PAYMENT OF COMPENSATION TOWARDS DAMAGES

IN REGARD TORIGHT OF WAY FOR TRANSMISSION LINES

3.1. Letter No.3/7/2015-Trans dated 15th

October 2015 of MoP (Annexure-I) contains

guidelines for payment of compensation towards damages with regard to right of way for

transmission lines. The following has been stated:

2. The Recommendations made by the Committee are hereby formulated in the form of

following guidelines for determining the compensation towards "damages" as

stipulated in section 67 and 68 of the Electricity Act, 2003 read with Section 10 and

16 of Indian Telegraph Act, 1885 which will be in addition to the compensation

towards normal crop and tree damages. This amount will be payable only for

transmission lines supported by a tower base of 66 KV and above, and not for sub-

transmission and distribution lines below 66 KV:-

(i) Compensation @ 85% of land value as determined by District Magistrate or any

other authority based on Circle rate/ Guideline value/ Stamp Act rates for tower

base area (between four legs) impacted severely due to installation of tower/pylon

structure;

(ii) Compensation towards diminution of land value in the width of Right of Way (RoW)

Corridor due to laying of transmission line and imposing certain restriction would

be decided by the States as per categorization/type of land in different places of


States, subject to a maximum of 15% of land value as determined based on Circle

rate / Guideline value / Stamp Act rates;

(iii) In areas where land owner/owners have been offered / accepted alternate mode of

compensation by concerned corporation / Municipality under Transfer Development

Rights (TDR) policy of State, the licensee /Utility shall deposit compensation amount

as per (i) & (ii) above with the concerned Corporation/ Municipality/ Local Body or

the State Government.

(iv) For this purpose, the width of RoW corridor shall not be more than that prescribed in

the table at Annex-2 and shall not be less than the width directly below the

conductors.

3. Necessary action may kindly be taken accordingly. These guidelines may not only

facilitate an early resolution of RoW issues and also facilitate completion of the vital

transmission lines through active support of State /UT administration.

4. All the States/UTs etc. are requested to take suitable decision regarding adoption of

the guidelines considering that acquisition of land is a State subject.

4. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER

ENVIRONMENT (PROTECTION) AMEN DMENT RULES, 2015

CEA vide letter dated 18.01.2016 had requested to furnish details of preparedness and

action plan in order to comply with revised water consumption and emission norms by

existing as well as new thermal units (to be installed from 01.01.2017 onwards) as per

Environment (Protection) Amendment Rules, 2015 notified by Ministry of Environment,

Forest & Climate Change (MOEF & CC) (Gazette Notification dated 07.12.2015). Vide

letter dated 20.01.2016 (Annexure- II) SRPC had communicated the same to the

concerned utilities. Information in this regard may kindly be arranged to be furnished to

CEA with a copy to SRPC. All thermal power plants are kindly requested to furnish

action plan to comply with Environment (Protection) Amendment Rules, 2015. SLDCs

are also requested to kindly take up the matter with thermal power plants in their state.

5. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY

Hon’ble CERC vide Order dated 13.10.2015 on Petition No. 11/SM/2015 in the matter of

Roadmap to operationalize Reserves in the country has directed as follows:

(b) The Commission reiterates the need for mandating Primary Reserves as well as

Automatic Generation Control (AGC) for enabling Secondary Reserves.

(i) All generating stations that are regional entities must plan to operationalise AGC

along with reliable telemetry and communication by 1st April, 2017. This would entail a

one-time expense for the generators to install requisite software and firmware, which

could be compensated for. Communication infrastructure must be planned by the CTU

and developed in parallel, in a cost-effective manner.


(ii) On the other hand, National/Regional/State Load Dispatch Centres

(NLDC/RLDCs/SLDCs) would need technical upgrades as well as operational

procedures to be able to send automated signals to these generators. NLDC /RLDCs

and SLDCs should plan to be ready with requisite software and procedures by the same

date.

(iii) The Central Commission advises the State Commissions to issue orders for intra-

state generators in line with this timeline as AGC is essential for reliable operation of

India’s large inter-connected grid.

(c) To start with, a regulated framework in line with the Ancillary Services Regulations

would need be evolved for identification and utilising of spinning reserves and

implemented with effect from 1st April, 2016. This framework may continue till 31st

March, 2017.

……………

(d) In the long term, however, a market based framework is required for efficient

provision of secondary reserves from all generators across the country. For this,

NLDC/POSOCO is directed to commission a detailed study through a consultant and

suggest a proposal to the Commission for implementation by 1st April, 2017, giving

due consideration to the experience gained in the implementation of Spinning Reserves

w.e.f. 1st April, 2016.

For SRPC consideration through TCC

6. IMPLEMENTATION OF SPS FOR CONTINGENCY OF 400 kV NELLORE -

NELLORE PS LINES AND DIFFERENTIAL PROTECTION

6.1. SRLDC vide letter dated 08th

October 2015 had stated that considering the operational

security of grid and to be N-1 secure it was important to provide a SPS for contingency

of one 400 kV NPS-Nellore lines. There had been a few cases in the past where distance

relay at NPS-Nellore had over-reached and tripped for remote end faults. Since Nellore-

NPS lines were short lines and considering their importance in the grid it is important to

avoid unwanted tripping of these lines due to mis-operation of protection system and

hence it was necessary to provide differential protection at the earliest.

6.2. The following had been noted in the earlier Meeting:

CTU had informed that NPS-Nellore line was a short line with thermal limit of 2,100

MW for the PGCIL section. Other section was constructed by MEPL/SEL and CTU

was in the process to obtain feedback on thermal capability. As per SRLDC, line

loading had crossed 1,700 MW only during low generation at Krishnapatnam. As

per deliberations in Open Access Meeting, the inter-connector i.e. NPS-Nellore could

also be kept open.


After deliberations, it had been agreed that during contingency, SRLDC would take

appropriate action in real time to contain line overloading.

6.3. The issue was further deliberated in the Special Meeting held on 20th

October 2015

(minutes available in SRPC website) wherein the following was noted:

SRLDC had stated that opening of NPS – Nellore (PG) is a sensitive issue as it would

require curtailment of STOA’s of the generators connected to NPS. As this has a

potential to trigger operational disputes between SRLDC and IPP’s on daily basis,

CTU has been requested to give basis for opening these lines by conducting proper

studies and reply/ advise SRLDC in a week’s time regarding the modalities of

opening NPS – Nellore (PG) lines including curtailment of STOA’s of generators.

It was also agreed that after receiving suitable inputs from CTU, a separate meeting

with all stake-holders would be convened to chalk-out the operational philosophy of

these lines.

6.4. Subsequently, SRLDC vide letter dated 20th

October 2015 (Annexure-III) and 02nd

November 2015 (Annexure-IV) addressed to CTU had sought clarity on the following

issues:

About the maximum power that can be evacuated from Nellore complex so that

curtailment of infirm power, STOA/MTOA transactions could be affected as per

Regulations.

If 400 kV Nellore PS- Nellore D/C line has to be opened to contain short circuit

level, the appropriate time frame for opening the line considering the availability of

generating units.

6.5. CTU vide letter dated 03.12.2015 (Annexure-V) had replied to SRLDC in this regard.

Subsequently SRLDC vide letter dated 07.12.2015 (Annexure-VI) had communicated

their views in this regard. In the 115th

Meeting of OCC, SRLDC had informed that they

were envisaging a Separate Control /Bid area for Nellore complex.

6.6. The issue regarding provision of differential protection for NPS complex was discussed

in the 50th

meeting of PCSC. After ascertaining opinion of PGCIL and Generators,

PCSC forum has agreed “in-principle” to provide line differential protection on all 400

kV lines of length less than 35 km emanating from Nellore PS.

7. METERING AND ACCOUNTING OF NTPC KUDGI STPP STAGE-I

7.1. This issue had been deliberated in the 29th

Meeting of Commercial Sub-Committee held

on 29th

September 2015 wherein the following had been agreed:

Metering and energy accounting of Kudgi STPP would be based on the SEMs on

400 kV outgoing feeders, HV side of 400/220 kV ICT and HV side of 220/11 kV

standby transformer.


Drawal of KPTCL at Kudgi STPP would be computed based on SEMs at HV side of

400/220 kV ICT & 220/11 kV standby transformer.

Kudgi STPP Stage-I metering arrangement is given below :

7.2. The following had been noted in the earlier Meeting:

KPTCL had stated that methodology agreed in Commercial Committee Meeting

was not in accordance with CEA Regulations or as per provisions of PPA.

Metering was required to be done on the 220 kV outgoing feeders.

NTPC had observed that the issue had been deliberated in the Commercial

Committee Meeting wherein it had been agreed that SEMs on HV side of

400/220 kV ICT would be considered as main meters for accounting purposes.

Similar was the case for some of the other NTPC stations.

After deliberations, it had been agreed that this matter whether metering and

accounting was to be done on 220 KV outgoing feeders or on HV side of

400/220 KV ICT be referred to CEA.

7.3. SRPC Secretariat had taken up the issue with CEA vide letter dated 27.10.2015

(Annexure-VII). A Meeting was convened by CEA and Minutes of the meeting are at

Annexure-VIII. NTPC vide letter dated 01.02.2016 (Annexure-IX) has stated the

following:

“7. Although CEA has clarified the queries raised by SRPC, but two issues still remain

open and need to be discussed and finalized. These issues are:

a) Installation and ownership of meters on HV and LV side of ICTs

b) Who will bear the losses in ICTs?

……………………………….


8. The matter was deliberated and agreed in the 29th

Commercial Sub-Committee

meeting held on 29.09.2015 that the metering and accounting has to be at HV side of

ICTs since Kudgi STPP ex-bus for the purpose of sale energy is at 400 kV busbars of

the Station. This will solve both the issues as brought out at para 7 above.

9. Alternatively it is proposed that:

a) Meters at HV and LV side of ICTs may be owned and installed by CTU and STU

respectively.

b) Losses in the ICTs may be treated as system losses or these losses may be accounted

in the REA and billed to the beneficiaries of the station in proportion to their drawl.’

7.4. The issue was further deliberated in 30th

CCM wherein it was noted that CTU would

provide meters on all 400 kV outgoing feeders while STU would provide on all 220 kV

outgoing feeders as clarified by CEA. However, there was no consensus on NTPC’s

proposal for treating ICTs’s loss as system loss. It was agreed to refer this issue to

TCC/SRPC.

8. STATUS OF GENERATION IN GENERATING STATIONS

8.1. The issue regarding low generation in KKNPP, NLC TS-II Expansion, NTECL and

NTPL was deliberated in the 28th

SRPC / 27th

TCC meetings. The following had been

noted:

KKNPP Unit-I had been taken out for refueling during the month of June 2015 with

projected outage schedule of 60 days.

NTECL had informed that the main constraint was in transportation of coal. Vallur

STPS was receiving only 2 rakes/day via Paradeep Port against requirement of 4

rakes/day. Negotiations were in the final stages for getting coal through the Dhamra

Port. Second grab unloader was planned to be commissioned by middle of November

2015 and movement of coal via Dhamra Port was expected by end of November

2015. Issues regarding pipe conveyor were also likely to be resolved soon. Station

was expected to achieve 80 % generation level (1,200 MW) by middle of October

2015 & 100 % availability by end November 2015.

TANGEDCO and NTECL would hold a meeting shortly to identify measures to

improve availability at NTECL.

NLC had informed that the units at NLC TS-II Expansion would stabilize and

sustained full load generation could be anticipated in about 2 months’ time.

In respect of NTPL, NLC had informed that there were issues in blending of coal

relating to clinker formation in unit-I and choking of burner mouths. NLC had

assured that within 1 month, NTPL units would also maintain full load. Presently,

these units were running mostly on imported coal and since boiler was not designed

for the same, the station was facing clinkering problems. With assured domestic coal

supply, blending issues would get resolved.


SRLDC had observed that increasing availability of power by scheduling NTPC

Kayamkulam to its full capacity also needed to be looked into. KSEBL had informed

that they had offered Kayamkulam power to Karnataka at an indicative cost of

Rs.6.50/unit, if requested for more than 2 months on RTC basis. PCKL had stated that

cost of Rs.6.50/unit appeared to be on a higher side. However, they would discuss

the matter with the Management/DISCOMs and revert back.

APGENCO had expressed concern that for supply of coal MCL was insisting for

inspection of Unit-II of Krishnapatnam JV after its CoD. All concerned agencies like

CEA, MCL etc had been duly invited to witness the full load test of Unit-II. However,

there had been no participation from MCL at that time. The coal supplied had already

been exhausted since supplied quantum was sufficient only for the full load test.

There was no coal available presently to demonstrate the capability to MCL. MCL

had clarified that as per recent policy, all new units commissioned could be supplied

coal only after due inspection by MCL. It was assured that they would depute a team

for inspection at the earliest

NTPC had informed that Simhadri TPS had received only 59% of the linkage in the

first two quarters. During September, the realization had been 73% which still

required improvement. NTPC was augmenting coal receipt through a new route from

Lingaraj. One NTPC loco from Kaniha had been diverted to Lingaraj. MCL had

informed that they had offered more than ACQ but on account of paucity of Railway

Wagons, realization had been less.

KPCL had stated that they would require about 2 Lakh T of coal for startup of Bellary

Unit-III. Coal synchronization was expected by end November 2015. MCL had been

requested to kindly expedite the sanction of coal for startup.

8.2. Subsequently, Unit-I of KKNPP was brought back on bars on 30th

January 2016. The

status of generation of some ISG stations is given below:

9. TTC / ATC

9.1. NRCE had issued operational guidelines for determination of Total Transfer Capability

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

Station Oct’15 Nov’15 Dec’15 Jan’16

KKNPP U1,

NPCIL

Generation

in MU

0 0 0 2.89

PLF 0 0 0 0.4%

NTECL,

Vallur

Generation

in MU

743.25 597.02 554.59 742.69

PLF 67% 55% 50% 67%

NTPL,

Tuticorin

Generation

in MU

301.76 374.86 410.55 501.93

PLF 41% 52% 55% 67%

NLC TS II

Exp

Generation

in MU

30.69 98.70 45.80 120.99

PLF 8% 27% 12% 33%


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

POSOCO had been advised to assess TTC considering temperature dependent thermal

ratings of lines / terminal equipment.

9.2. Temperature dependent thermal rating of lines / terminal equipment affecting TTC of SR

import was to be taken up.

9.3. NLDC vide letter dated 01.02.2016 (Annexure-X) had furnished list of transmission

elements affecting TTC/ATC to SR and had suggested that any planned outage on these

elements needs to be appropriately studied.

9.4. SRPC vide letter dated 04.02.2016 (Annexure-XI) had replied to NLDC letter. It was

also enquired whether dynamic line loadings had been considered. Further, when one

line of 400 kV Ramagundam- Bhadravathi was under shutdown, there had been 250

MW of curtailment in TTC.

9.5. During shutdown of 765 kV Raichur-Sholapur Ckt II and Bhadravathi Pole I, ATC of

500 MW was approved through WR-SR link, though there was one pole of Bhadravathi

(500 MW), one 765 kV Raichur-Sholapur circuit and two circuits of 765 kV Sholapur –

Kudgi (charged at 400 kV) available.

9.6. POSOCO is requested to kindly appraise the forum about ATC computations and

whether dynamic line loadings are being considered as per directions of Hon’ble CERC.

9.7. Transfer capability determination by States

In the 4th

meeting of NPC held on 10th

December 2015 (MoM dated 1.1.2016 enclosed

as Annexure-XII), it had been decided that to begin with, power system study for

assessment of operational limits / power transfer capability for each state would be done

by the concerned RLDC in association with concerned SLDC. Monthly TTC/ATC

would be uploaded by SLDCs in their respective websites and also communicated to

concerned RLDC & NLDC subsequently.

10. REVIEW OF ULDC / SCADA/COMMUNICATION

10.1. In previous Meetings, the following had been noted:

Review of SCADA and Communication availability was being carried out in the

OCC/Special meetings.

APTRANSCO had expressed concern over mismatch and wrong data in new SCADA

system. APTRANSCO vide letter dated 06.01.2016 (Annexure-XIII) had informed

that large variation was observed between real time SCADA data and SEM data

furnished for Deviation account for 09.11.2015 to 15.11.2015 which caused AP to

pay Rs. 2.26 Crores as deviation charge.


SRLDC had expressed concern over interruption in real time data and requested

PGCIL to address this issue at the earliest. Dedicated Officers were required from

PGCIL side to improve availability of SCADA data to SRLDC.

NLDC had pointed out that this was a serious issue since it gave a misleading picture

to the system operators.

PGCIL had stated that they were seized about this issue. A core group was looking

into this issue and they would come out with a solution soon.

10.2. Matter regarding failure in providing data with redundant channel/path to SRLDC

(resulting in violation of Grid Code and system security) had been referred by SRLDC to

SRPC under Clause 1.5 of IEGC 2010. Subsequently, SRPC had taken up the issue with

the concerned. Utilities had been requested to examine the matter urgently and ensure

strict adherence to the provisions of IEGC/CEA Regulations. A Special Meeting to

deliberate on communication issues was also held on 19th

November 2015 in SRPC

Bengaluru (Minutes available at SRPC website).

10.3. In the 115th

OCC Meeting, it was again felt that there should be an active monitoring

system in place. Interruption in real time data was a matter of concern since commercial

and grid security issues were involved. Availability of SCADA was also being noted by

higher bodies.

10.4. Hon’ble Commission has issued Order dated 2nd

February 2016 in respect of Petition

No.7/SM/2014. The following direction merits attention please:

‘14. Under the Grid Code, it is the responsibility of all users, STUs and CTU to provide

systems to telemeter power system parameters in line with interface requirements and

other guideline made available by RLDC and associated communication system to

facilitate data flow up to appropriate data collection point on CTUs system.

Telemetry of on-line operational data is not only essential for effective monitoring of

grid but also forms key input for effective running of State estimation and other EMS

tools at RLDC and SLDCs, which are essential for reliable and secure operation of

the grid. In view of the critical importance of telemetry and associated

communication system for ensuring reliability in operation of the grid and optimum

utilization of the transmission system, there is an imperative need for all users to

establish the telemetry and associated communication system in time bound manner

so that the power system operation may be most reliable and optimum. Moreover, in

view of the requirement of communication system for a generating station and sub-

station, the planning should be done in advance by the generating company and

transmission licensee to ensure that necessary system are in place before

commissioning of generating station or sub-station to take care of the communication

requirements even at the time of injection of power infirm by a generating station and

sub-station during testing.

……………………………..

17. We further direct all the utilities/generating companies which have to still establish

telemeter power system parameters as per details given in para11 above to provide

data to RLDCs/SLDCs as per the provisions of the Grid Code and CEA Grid


Standards Regulations by 31.7.2016. If the utilities/generating companies do not

comply with our directions, it will be construed as non-compliance of the order of the

Commission and appropriate proceedings under Section 142 of the Electricity Act,

2003 shall be initiated against such utilities/generating companies. NLDC is directed

to submit user- wise latest status of telemetry, by 31.8.2016.

18. NLDC and respective RLDC are directed to up-date the status of telemetry every

month at their web-site and persistent non-availability of data from the generating

stations/sub-stations be taken up in RPC meetings for appropriate direction and

action.’

The matter needs to be deliberated as per the orders of Hon’ble Commission.

10.5. In the 116th

OCC Meeting (10.02.2016), it was agreed that PGCIL representative would

be present at SRLDC to sort out SCADA/Communication issues pertaining to Raichur,

Kurnool, Khammam, Warangal, Nagarjunasagar, Ramagundam, Bhadravathi and MEPL

on priority basis. Subsequently, other issues would be taken up. It was also agreed that

state wise reconciliation would be carried out. It was noted that it may take around one

month time for each state. Two officials from SRLDC and state (one each from SCADA

and Grid Operation) would sort out the issues. Drawal computation methodology would

also be reviewed. AP SCADA validation would be carried out from 15.02.2016

onwards.

11. UPCOMING TRANSMISSIONSYSTEM

11.1. Pending transmission elements in WR and SR for proper utilization of 765 kV

Raichur-Sholapur line (Out of planned 18 elements)

11.1.1. Updated status of pending transmission elements in WR and SR for proper utilization

of 765 kV Raichur - Sholapur lines (out of planned 18 elements) is furnished below

please:

Sl.

No

Name of

Transmission

Element

Exe.

Agency Sch. CoD Expected

date

Remarks

1 400 kV Gooty-

Tumkur D/C line

PGCIL June 2014 Commissio

ned on

01.12.2015

2 400/220 kV , 2 x

500 MVA, 63

MVAR Reactor

Tumkur S/S

PGCIL June 2014 Commissio

ned on

01.12.2015

Downstream network

not available

3 400 kV Tumkur-

Yelahanka D/C line

PGCIL June 2014 Severe RoW problem.

400 kV Yelahanka S/S

is ready.


11.1.2. The following had been noted in earlier Meetings:

Downstream system by KPTCL was needed to be expedited to reap the benefit. LILO

of 400 kV Nelamangala – Hoody along with 400 kV Tumkur – Yelahanka together

could help in further evacuation.

SRLDC had stated that downstream system both at Tumkur and Yelahanka was

required for increasing the ATC.

Constituents had expressed that LILO of 400 KV Nelamangala - Hoody at Yelahanka

and Tumkur -Yelahanka line (even without downstream at Yelahanka) could help

increase ATC and hence PGCIL may prioritize commissioning.

KPTCL had informed that regarding Yelahanka PG- Yelahanka (KPTCL) link,

special cable (international source) was required and the same was being retendered.

Works could take about 6/7 months’ time (5 kM) once the award was in place.

KPTCL had informed that in respect of downstream system at Madhugiri, while

contract for two downstream lines was already in place, the other two lines may come

in a time frame of about one year. Out of four 220 kV lines planned for Tumkur

downstream system, two short lines (79 kM) were likely to be completed in 4 months

(3 months from the date of resolution of RoW issues). With these lines, about 350-

400 MW of evacuation from Tumkur would be possible. Other D/C line would come

in about one year.

Downstream system from Tumkur S/S was:

220 kV Tumkur – Antharasana Halli D/C

400 kV Tumkur S/S – 220 kV Tumkur S/S D/C

Tenders for the above line had been placed on 18.03.2015 and it would

take 18 months for completion.

Downstream network from Yelahanka S/S was:

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

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

11.2. Upcoming inter-regional transmission schemes

11.2.1. The updated status is furnished below please:

S.

No. Transmission Element Remarks

a) 765 kV Kudgi (PG) – Kolhapur D/C

line (charged at 400 kV)

Ckt I : COD on 19.11.2015

Ckt II : COD on 11.12.2015

b) 765 kV Wardha – Nizamabad D/C

line

Original Schedule by May 2018

PGCIL trying to complete the

system by May 2017

c) WR-SR 6000 MW HVDC Bipole

Link [Raigarh (Chhatisgarh) -

Pugalur-Trichur (TN/KER)]

2018-19

Tendering activity is continuing.

Land had been acquired at

Pugalur

Land identified at Trichur and

acquisition would start

Technical specifications are

being finalized with 10 %


overload capacity

d) 765 kV Angul - Srikakulam PS D/C

line

By August 2016, other associated

elements by December 2016

e) Additional inter-Regional AC link for

import to Southern Region, i.e.,

Warora-Warangal - Hyderabad-

Kurnool 765 kV link

TBCB, PFCCL- BPC– Bidding yet to

commence. RFQ inputs furnished by

CTU. Some scope of work/ reactive

compensation modified and RFQ

modified accordingly.

f) System strengthening within SR for

transmitting power beyond Vemagiri

TBCB- RECTPCL-BPC– SPV had

been incorporated on 06.04.2015 and

RFQ issued on 12.04.2015. Some

scope of work/ reactive compensation

modified.

11.2.2. Updated status of upcoming inter regional scheme is furnished at Annexure-XIV.

11.2.3. The following had been noted in earlier Meetings:

SRTS-I & II had informed that tendering activities in respect of Raigarh- Pugalur

-Madakathara HVDC were continuing. Land for the HVDC terminal at Pugalur

had been acquired. Land for HVDC terminal at Madakathara (Thrissur) had also

been identified and acquisition would commence shortly.

765 kV Wardha- Nizamabad D/C line was being advanced on the request of

Telangana Govt. and was now scheduled for May 2017. System beyond Vemagiri

was however coming under TBCB route and the benefits of increase in import

capacity could be achieved only after commissioning of the downstream system.

11.2.4. From 16th

December 2015, consequent to commissioning of 765 kV Kolhapur-Kudgi II

(charged at 400 kV) and 765 kV Raichur-Kurnool I, TTC on WR-SR corridor had been

enhanced by 800 MW. Entire ATC of 5,900 MW to SR had been allocated under

LTA/MTOA.

11.3. Status of various Associated Transmission Systems (ATS) of upcoming generators

11.3.1. Common System Associated with NTPL / Costal Energen Private Ltd / Ind-

Barath Power Ltd

11.3.1.1. Updated status of associated links is furnished below:

Transmission

Elements

Line

Length

(ckm)

Implem

enting

Agency

Sch

COD

Ant

COD/

Act

COD

Constraints/

Remarks

765 kV D/C Tuticorin

PS - Salem PS line

(Dharmapuri) (initially

charged at 400 kV)

735 PGCIL Dec'14 Jun’

2016

400 kV D/C Salem PS

– Salem line

120 PGCIL Line is ready.

765 kV S/C Salem PS

(Dharmapuri) -

Madhugiri P S line

244 PGCIL Dec'14 Mar’ 16 Severe ROW

problems in

Karnataka.


(initially charged at

400 kV)

Critical.

765/400 kV Salem PS

(initially charged at

400 kV)

PGCIL PS is ready

400 kV D/C Coastal

Energen – Tuticorin

PS

Coastal

Energen

April 16 CEA in its

meeting held on

11.12.2015 has

advised Coastal

Energen to

complete the line

by April 16,

2016.

11.3.1.2. The following had been noted in earlier Meetings:

NLC had stated that both the units at NTPL had been commissioned and there

should not be any evacuation constraints for NTPL units.

Coastal Energen had enquired whether 2 units of NTPL and 1 unit of Coastal

Energen could be evacuated through the existing arrangement. D/C line from

Coastal Energen to Tuticorin Pooling Station would be completed in 6-8

months.

SRLDC had pointed out that 400 kV Madurai- Udumalpet was getting

overloaded under certain conditions. ATS for Coastal Energen also comprised

of upstream system from Tuticorin PS which was expected only by June 2016.

CTU had stated that as was known LTA would have more priority than MTOA.

11.3.1.3. Subsequently, a Meeting was held at CEA on 11th

December 2015 regarding “2x600

MW Mutiara Thermal Power Project-Permission for Synchronization and declaration

of COD of unit -2” (Minutes at Annexure-XV). It had been noted that total

evacuation from the two projects i.e. Coastal Energen & NTCL would be restricted to

1,350 MW up to 30.04.2016. Coastal Energen would firm up and submit their

schedule of completion of the dedicated transmission line up to Tuticorin pooling

station. They would give assurance that this line will be completed by 30th

April 2016

i.e. before onset of wind season in that area.

11.3.1.4. Coastal Energen vide letter dated 07.01.2016 (Annexure-XVI) had proposed an SPS

in Tuticorin PS-CEPL-NTPL Complex for running both units of CEPL till June, 2016

by which time both CEPL and PGCIL would complete their respective lines.

11.3.1.5. The issue was discussed in the 50th

PCSC meeting held on 27.01.2016, wherein

SRLDC had stated that SPS proposed could not be agreed to in its present form on


account of the following reasons:

Generation from second Unit of CEPL has not been tied up (for accommodating

which the present SPS is being proposed)

In the proposed SPS, details of loads to be held to balance LGBR in event of

tripping of one of the Units had not been spelt out;

In the event of non-operation of SPS, there is a real chance that end-equipment at

NTPL switchyard may get damaged due to limitation imposed by the bus-bar

rating.

TANTRANSCO opined that since loads are yet to be identified for the proposed

SPS, the issue be discussed in the forthcoming Meeting of OCC. A Meeting on

this issue has now been scheduled to be held on 23rd

February 2016.

11.3.2. Transmission system associated with IPPs (IL&FS) of Nagapattinam/Cuddalore

Area

11.3.2.1. Updated status of associated links is furnished below please:

(i) Transmission system associated with IPPs of Nagapattinam / Cuddalore Area –

Package A

Transmission

elements

Line

Length

(ckm)

Imp.Agenc

y

Sch

COD

Ant.

COD

Constraints/

Remarks

Nagapattinam PS-

Salem New

765 kV D/C line

211.73 Powergrid

Nagapattina

m-

Madhugiri

Transmissio

n Company

Limited

(PNMTCL)

(A

subsidiary

of PGCIL)

Mar’

15

Mar’16

Salem New –

Madhugiri 765

kV S/c line.

234.46 Jun’ 16 Severe RoW issues

being faced in

Karnataka section.

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

from IL&FS (2x600MW)

Transmission

Elements

Line

Length

(ckm)

Imp.

Agency

Sch

COD

Ant

COD

Constraints/

Remarks

LILO of 2nd

Ckt of

Neyveli - Trichy 400

kV D/C line at

Nagapattinam PS

44 PGCIL Jul'15 Complete

d on

27.09.20

15


Strengthening of

Neyveli TS -II to

Neyveli TS-I

expansion link with

higher capacity

conductor

28 PGCIL Jul'15 Declared

on COD

from

09.11.20

15

11.3.3. Evacuation of Power from HNPCL (1,040 MW) Power Plant

11.3.3.1. Updated status of associated links under APTRANSCO’s scope is furnished

below:

Transmission

Elements

Line

Length

(ckm)/

MVA

cap.

Implemen

ting

Agency

Target

Date

Target

date

completi

on

Constraints/ Remarks

Startup Power

Line from M/s.

HNPCL TPP to

400/220 kV

Kalpakka SS

7 APTRANS

CO

Line Charged on

07.02.2014

400 kV TM D/C

Line from

HNPCL -

Kamavarapukota

S/S (Lot-I, II &

III)

Lot - III

200 ckm

(100 x 2)

APTRANS

CO

Jul ‘15 Oct’16

as

informed

in 27th

TCC

Works delayed due to

severe resistance from

farmers, water logging,

collapsible soil,

existing crops &

frequent rains.

However construction

activity is being

continued with the help

of Revenue and other

concerned authorities.

400 kV TM D/C

Line from

Kamavarapukota

S/S - Vemagiri

400 kV S/S

APTRANS

CO

Apr’17 LoI issued on

04.09.2015. Purchase

Order issued on

03.11.2015

400 kV TM D/C

Line from

Kamavarapukota

S/S - 400 kV

Chinna

Korukondi S/S

212 APTRANS

CO

Sept. ‘15 Oct’16

as

informed

in 27th

TCC

LoI issued on

15.07.2013. Delaying

due to standing crops

and compensation

issues.

Kamavarapukota

Substation

2x315

APTRANS

CO

Mar ‘16 Oct’16

as

informed

in 27th

TCC

Works awarded.


2 Nos. of 400 KV

Bay Extensions at

existing 400/220

KV Kalpaka S/S

of HNPCL

APTRANS

CO

Oct’16

as

informed

in 27th

TCC

All works completed

for 1 No. of 400 KV

Bay on 07.02.2014

11.3.3.2. Updated status of associated links under TSTRANSCO’s scope is furnished below:

Transmission

Elements

Line

Length

(ckm)/

MVA

cap.

Implemen

ting

Agency

Target

Date

Target

date

completi

on


400 kV TM D/C

Line from Chinna

Korukondi - 400

kV Suryapet S/S

212 TSTRANS

CO

2016-17 Works awarded in

March 2014. Tower

erection and stringing

under progress.

Suryapet S/S -

Nandiwanaparthi

S/S 400 kV Quad

D/C Line

240 TSTRANS

CO

Mar’15 2015-16 Works awarded in Sep-

13. Stringing

completed. OPGC

4.682 kM under

progress.

400 kV Quad D/C

Line from

Nandiwanaparthi

S/S -

Shankarapally

S/S

222 TSTRANS

CO

Mar’15 2015-16 Works awarded in Sep-

13.Under Progress.

Suryapet

Substation

400/230/132 & 2

Nos. of 400 KV

Bay Extensions at

400 KV

Shankarapalli S/S

2x315

TSTRANS

CO

Mar’15 2015-16 Work awarded in Sep’

2013 and under

progress


On an observation of SRLDC, APTRANSCO had agreed that maximum

evacuation from Vemagiri complex including HNPCL would be restricted to 600

MW.

APTRANSCO had stated that as per their studies on account of changes in system

configuration, around 750 MW of power injection could be possible from the

complex.

SRLDC had stated that generation at Vemagiri Complex had increased due to gas

pooling scheme. With HNPCL generation, injection limits at Vemagiri complex

needs to be ascertained through studies. APTRANSCO had stated they would

participate in the joint study and adhere to the limits finalized in the study.

11.3.3.4. A joint study comprising members from APTRANSCO, SRLDC and SRPC was


conducted to assess capability of evacuation of Gas Generation from Vemagiri

Complex and Hinduja TPS connected at 400 kV Kalpakka SS. Requirement for study

came on account of LILO of APTRANSCO owned 400kV Vemagiri- Nunna line-1 at

400kV Sattenapalli SS in the month of October, 2015.

From the study results (Annexure-XVII) the following was observed:

(i) Vemagiri Complex: With the present network, the entire generation of Vemagiri

Complex (1,450 MW) can be evacuated without any constraint. However, with nil

generation at VTS Stage 4 (Unit 7:500MW), the generation at Vemagiri has to be

reduced to 660 MW.

(ii) Hinduja TPS: With the present system, only 575 MW out of the total generation

can be evacuated without any constraint. However, with zero generation at VTS Stage

4 (Unit 7:500MW), the combined generation. (Vemagiri complex + Hinduja TPS)

needs to be restricted to 660 MW.

11.3.4. Transmission system of KPTCL for evacuation of power from Yermarus TPS

(2x800 MW)

11.3.4.1. Updated status of associated links is furnished below:

Transmission elements Imp.Age

ncy

Line

Length

(ckm)/

MVA

cap.

Sch. COD Constraints/ Remarks

Bellary 400 kV PS near

‘BTPS’

KPTCL Jul’16(As

informed

by JSWEL)

Gulbarga 400/220 kV

substation

KPTCL 2x500 New Scheme in place of

old one is approved in

56th TCCM meeting held

on30.11.2013.

Land is in possession of

KPTCL. Preliminary

survey work of 400 kV

line is completed.

Estimate to be prepared

Yeramarus TPS -

Gulbarga 400 kV D/C line

(QM)

KPTCL Estimate to be prepared.

400 kV switching station

at Chikkanayakanahalli

(C.N Halli) near “Loop in

Loop Out” (LILO) point

on the Nelamangala –

Talaguppa 400 kV lines to

Hassan.

KPTCL Land identified. Land

Acquisition is under

process.In 39th

SCPSPSR

KPTCL had suggested for

a step down station with 2

x 315 MVA, 400/220 kV

ICTs with 220 kV

connectivity.


LILO of both the circuits

of Nelamangala –

Talaguppa 400 kV lines to

the proposed pooling

station near CN Halli.

KPTCL CN Halli land identified

near the intersection point

of all the proposed lines.

Termination of 400 kV

D/C line feeding 400/220

KV station at Hassan from

Nelamangala – Talaguppa

line at CN Halli 400 kV

pooling station.

KPTCL After CN Halli land

identification, survey

would be taken up.

Yermarus TPS - Bellary

Pooling Station 400 kV

D/C line with quad moose

conductor

KPTCL 300

(400 kV

MC Line

(5.138

Kms) and

400kV

DC line

(137.355

Km)

totally for

a route

length of

142.493

Kms)

DPR approved on

26.02.2015. Tendered on

09.03.2015. Techno

Commercial bids opened

on 21.05.2015. Price bids

opened on 01.07.2015.

The works have been

awarded.

Bellary Pooling Station -

C.N.Hally 400 kV D/C

line with quad moose

conductor

KPTCL 360 Survey using MST

conducted and reports

submitted to zonal office

vide ltr no:1682-83

Dt:30.06.15 and the same

is submitted for approval

to CEE(P&C) vide

ltr.no.2504-06 dt 7.7.2015

Bellary PS to Madhugiri

line (765/400kV V.N.pura

substation (PGCIL)

a) Madhugiri to Rampura

limits): 400kV DC line

with Quad Moose ACSR

(188.74 Kms)

b) Bellary pooling Stn 400

kV to Rampura limits

(Kelagina Kanavi):

(43.018 Kms)

KPTCL 380

22-Dec-16

Under Execution by KEC

International Ltd

DPR approved on

26.02.2015. Tendered on

09.03.2015. Award to be

issued.

Bellary TPS – Bellary



conductor

KPTCL 10 Survey work in

progress.In 39th

SCPSPSR

KPTCL had suggested to

drop the proposal.



KPTCL had informed that 400 kV Tumkur-Bellary PS D/C line had been awarded

and was expected to come along with Bellary PS with schedule of one and half

years i.e March 2017. They were trying to compress construction to one year

against schedule of one and half year. Land identification was completed in C N

Hally but KPTCL was targeting this system in the second stage. CEA had been

requested to allow 500 MW of evacuation from Yermarus coupled with drawal at

Tumkur. It was assured that 500 MW of injection from Yermarus would not be at

the cost of regional ATC.

De-link 400 kV S/C line

running between RTPS-

BTPS-JSW-Guttur with

‘BTPS’ and JSW Bus so

as to retain direct

connectivity between

RTPS and Guttur

KPTCL

Only after all other

Transmission Elements

under Stage I are

commissioned. In 39th

SCPSPSR KPTCL had

suggested retaining the

LILO at BTPS only.

JSW TPS – Bellary



conductor

KPTCL Jul’16(As

informed

by JSWEL)

Only after all other

Transmission Elements

under Stage I are

commissioned.

KPTCL/JSW to discuss to

take up this work as

dedicated transmission

line by the generator.

400 kV CN Halli –Mysore

D/C (QM)

In 39th

SCPSPSR KPTCL

had proposed that the line

could be taken under

Southern Region system

strengthening.

400 kV Tumkur

(Madhugiri)–Mysore D/C

(QM)

In 39th

SCPSPSR KPTCL

had proposed that the line

could be taken under

Southern Region system

strengthening.

400/220 kV SS at Bellary

PS or JSWEL 2 x 315

MVA)

In 39th

SCPSPSR KPTCL

had proposed the SS.


SRLDC had pointed out that 400 KV Hiriyur - Nelamangala lines were getting

overloaded and ATS was not ready for Bellary Unit-III and Yermarus TPS.

Generation from the Complex maybe required to be regulated by Karnataka

SLDC.

SRLDC had stated that only 2,090 MW of evacuation would be possible from

Raichur TPS, Yermarus TPS & Bellary TPS. KPTCL pointed out that with the

present network about 2,600 MW of power was already getting evacuated. SRLDC

confirmed that 400 kV N/W had only been considered in the studies.

11.3.5. Transmission System required for evacuation of power from Kudgi TPS (3x800

MW in Phase-I) of NTPC Limited

11.3.5.1. The updated status is furnished below:


KPTCL had informed that one 220 kV line was passing close to Kudgi

switchyard (3 kM). LILO of this line would be completed by October 2015 so

that NTPC could avail startup power. Three 220 kV D/C lines were planned

evacuation lines at 220 kV level to Vajramatti, Basavana Bagewadi and Bijapur.

The Vajramatti line had just been awarded and could take about 1 year. There

were some RoW issues in that area. Construction from B Bagewadi and Bijapur

ends had already commenced and about 50 % of the lines are completed

KPTCL had stated that they should be allowed dedicated ATC since radial loads

would be required to be provided by them besides temporary LILO arrangement

of 220 KV line. This would purely be a temporary arrangement till Kudgi unit

Transmission

Elements

Imp. Agency Scheduled

CoD

Revised

Target

Date


400 kV Kudgi TPS

– Kudgi (PG)

2xD/C Line

M/s Kudgi

Transmission

Limited

(L&T

Infrastructure

Development

Projects Ltd.)

Feb-15 2015-16

One D/C line Kudgi TPS –

Kudgi (PG) declared on

deemed CoD from 04.08.15.

Kudgi (PG)-

Tumkur 765 kV

D/C Line

Dec - 15 2015-16 Under Progress

Tumkur -Bidadi

400 kV D/C

(quad) Line

Dec - 15 2015-16 Under Progress

400/220 kV ICT 1

& 2 at NTPC

Kudgi Switchyard

NTPC

400 kV Bus

Reactor -2

NTPC


commences generation. SRPC had noted that a Meeting would be held to

deliberate on the proposal of Karnataka for which TCC had agreed “ in

principle”.

11.3.5.3. Subsequently PCKL vide letter dated 17.12.2015 (Annexure-XVIII) had requested

to intimate status of corridor allocation under special ATC to Karnataka. SRPC vide

letter dated 23.12.2015 (Annexure-XIX) had communicated to PCKL that since

entire ATC had already been allocated under LTA/MTOA and complete system being

an inter-regional IST system, special ATC to Karnataka appears to be not feasible. It

was also indicated that this matter had already been discussed with POSOCO. NLDC

vide letter dated 21.01.2016 (Annexure-XX) had communicated similar aspects to

PCKL. It had been suggested that PCKL may apply for STOA in line with CERC

Regulations and in case of margins in the transmission system on day to day basis, the

same would be processed accordingly.

11.3.5.4. NTPC Kudgi had availed startup power as a HT consumer for the period from

29.10.2015 to 30.11.2015 through LILO of 220 kV Ballurthy - Kudgi line.

Subsequently, NTPC Kudgi was availing startup power through ISTS Grid.

11.3.6. Transmission System for evacuation of power from Singareni Collieries

Generating Project (2 x 600 MW)

11.3.6.1. The following is the status update:

Transmission

elements

Length

(ckm/MVA

capacity)

Imp. Agency

Sche

duled

CoD

Target

date of

Compl

etion

Constraints/

Remarks

1. 400 kV Singareni- Gajwel in two parts

a) 400 kV Jaipur

(Singareni) -

Rangampet D/C

(Quad)

149.636

TSTRANSCO

2015-16

Works awarded on

06.03.2013. Work

awarded to M/s Best

& Crompton

GVPR(JV), Hyd.

Under Progress.

b) 400 kV

Rangampet- Gajwel

D/C (Quad)

174.852

TSTRANSCO

Comp

leted

2. 400 kV Singareni-Nirmal in two parts

a) STPP, Jaipur -

Jagityal 142

TSTRANSCO Works Awarded on

Nov’15 and under

progress

b) Jagityal - Nirmal

156

TSTRANSCO Feb

17

Works Awarded on

Oct’15 and under

progress


11.3.7. Transmission System for Rayalaseema TPS (600 MW)

11.3.7.1. The following is the status update:

11.4. Status of upcoming links having impact on S1-S2

11.4.1. Following is the updated status:

Sl.

No. Transmission Element Schedule

Expected

Commissioning

Date

Remarks

1 400 kV Somanahalli-

Dharmapuri PS

June-15 Feb-16 The works under Tamil Nadu

portion had been completed

and severe RoW problems for

35 Kms. stretch of Karnataka

portion.

45 days shutdown for Hosur-

Salem line would be required

for stringing of this line.

PGCIL would coordinate with

Tamil Nadu.

2 400 kV Mysore- May 2015 COD on

Transmission

elements

Length

(ckm/M

VA

capacity)

Imp.

Agency

Schedul

ed CoD

Target

date of

Completi

on


RTPP (Stage -

IV) - Chittoor

TM D/C Line

(a). RTPP -

Pedda Jamgam

Palli (P.J.Palli)

(b). P.J. Palli-

Chittoor

(c)

Muddanur(RTPP

)-

Chinakampally

432

120

APTRA

NSCO

Mar 16

Mar 16

Works Awarded on

02.04.2014 and under

progress. Tower erection

completed.

Works under progress.

400/220 kV,

Kalikiri S/S 2x315

MVA

APTRA

NSCO

LoI issued on 16.09.2015.

PO is placed in Nov-15.

LILO of both

circuits of

Rayalseema IV-

Chittoor 400 kV

D/C line| at

Kalikiri

APTRA

NSCO

Tenders under preparation


Kozhikode 16.10.2015

3 400/220 kV 2 x315

MVA SS at Kozhikode COD on

16.10.2015

4

400 kV Mangalore

(UPCL ) -Kasargode-

Kozhikode

In the Meeting taken by

Secretary(Power), MoP on 18th

August 2015 it was noted that

this line was considered in the

transmission plan.

11.4.2. In earlier Meetings the following had been noted:

PGCIL had informed that regarding 400 kV Dharmapuri - Somanahalli line, DC

(Urban) had ordered compensation of 100 % of fair value for tower footing and 55

% for line corridor. With this, cost of 30 kM line was working out to as high as Rs

90 crore. Hon’ble Power Minister of Karnataka was scheduled to make a site visit

shortly to look into compensation issues etc.

KSEBL had suggested that ICTs at Areakode substation be enhanced to 3x315

MVA or 2x500 MVA from the existing 2x315 MVA in view of the increased

power flow towards North Malabar region. CTU had agreed in principle for the

additional ICT and stated that the requirement and capacity (315 or 500 MVA)

could be finalized in the Standing Committee. Space actually available in the

substation was also required to be kept in mind

KPTCL had stated that they had already referred issue of 400 kV UPCL-

Kasargode- Kozhikode line to the Standing Committee.

11.5. Critical Intra-regional transmission elements

11.5.1. The following is the status update:

Sl.

No. Transmission Element Expected CoD Remarks

1 765 kV Salem- Tumkur

By PGCIL

Through TBCB

March 2016

June 2016

Severe RoW problem near Tumkur.

2 400 kV Edamon-Kochi Dec’2016 Govt. of Kerala issued revised G.O

in Jan’2015 with enhanced

compensation. Being monitored

under PRAGATI

3 765 kV Raichur-Kurnool COD on

15.12.2015

4 400 kV Khammam– N’Sagar

D/C

COD on

03.01.2016

TBCB

11.5.2. The following was noted in earlier Meetings:

KSEBL had informed that associated works regarding 400 kV Edamon-Kochi may

commence after two weeks. KSEBL had assured of full assistance and cooperation

in this regard.


PGCIL had informed that 400 kV Edamon-Kochi was being monitored under

‘PRAGATI’ (Pro Active Governance And Timely Implementation). Chief

Secretary, Govt. of Kerala had conducted a meeting with DCs, SPs and senior

police officials to sort out the survey/sorting of RoW issues. Detailed survey was

still pending in about 20 kM stretch which was required to finalize tower schedule

etc. With considerable efforts, the contract which was originally entered in 2007

had been revived. Immediately, a Task Force had also been formed to expedite

addressing of various issues. With the support of Kerala Govt. and MoP, this line

was likely to move ahead.

Regarding 765 kV Tumkur - Dharmapuri, PGCIL had informed that the line was

crossing four districts in Karnataka (Tumkur, Kolar, Chikkaballapur & Bengaluru

Rural) and RoW issues were being addressed in a stepwise manner.

11.6. 400 kV Trichur-Kozhikode line (Madakkathara-Areakode)

In the 27th

Meeting of SRPC it had been agreed that KSEBL could execute Madakkathara-

Areakode and Kozhikode-Mylatti lines after due ratification by Standing

Committee/CEA. In the 28th

SRPC Meeting, KSEBL had informed that KSEBL would

get the modifications ratified by the Standing Committee of PSPSR. Works would only

be taken up subsequently.

11.7. Closing of Upper Sileru-Balimela Line

In the 27th

TCC Meeting, APTRANSCO had stated that downstream lines such as Lower

Sileru - Bommur were getting overloaded and hence it may not be feasible to close the

lines on sustained basis.

11.8. Utilization of Jeypore - Gazuwaka link to its full capacity i.e 1,000 MW

11.8.1. The following had been noted in .earlier Meetings:

TSTRANSCO had expressed concern that the link capacity needed to be utilized

fully and some short term measures need to be identified. This could also involve

shifting of any STATCOM from other parts of the country to Gazuwaka.

SRLDC had stated that in the present Grid scenario due to low short circuit level of

Gazuwaka and upstream line loadings in GRIDCO system power up to 750 MW

only could be imported. NLDC had observed that Jeypore had a low fault level of

2,400 MVA while other adjoining nodes were having fault level of about 4,000

MVA. In case of any line tripping, the fault levels are reducing. Severe voltage

oscillations were being observed even for 100 MW upstream change in

load/generation

CTU had intimated that STATCOM along with mechanically switched

reactors/capacitors were planned to be commissioned in 2 to 3 years’ time frame

(tendering stage) which would then stabilize voltage variation at Jeypore. Around

650 MW was being permitted on this link. Few issues such as Pole-I being an old


installation, non-commissioning of Talcher- Behrampur- Gazuwaka backup system

were constraints in utilizing the link to full capacity.

After deliberations, it was agreed that the issue would be discussed in a Special

Meeting to be held with participation from CTU to assess possibility of short term

measures to improve import capability. Subsequently, a Meeting with

ERLDC/ERPC could be held.

11.8.2. In the Special Meeting held on 30.10.2015 (minutes available in SRPC website) the

following had been noted:

CTU representative informed that to overcome above stated issues, one

STATCOM has been approved at Jeypore along with other proposed STATCOMs

in the Eastern Region in SCPSPSR-36. However, as all STATCOMs proposed in

the Eastern region are planned to be implemented through PSDF funding, there is a

delay in clearing procedural formalities, and steps are being taken to expedite the

same. .

11.9. NLDC vide letter dated 8th

January 2016 (available in NLDC website) had highlighted

prioritization of transmission system under implementation to relieve congestion.

ISTS system already approved and commissioning of which was expected to relieve

congestion in respect of SR as given below:

Talcher backup system being executed by TTCL and approved timeline was

Sep’2013

HVDC Raigarh-Pugalur Bi-pole

765 kV Wardha-Hyderabad D/C

765 kV Angul-Srikakulam –Vemagiri

System beyond Vemagiri

765 kV Kudgi- Madhugiri D/C (to be charged at 400 kV)

400 kV Madhugiri-Bidadi

400 kV Madhugiri-Yelahanka

400 kV UPCL-Mylatti-Kozhikode

765 kV Tumkur PS- Dharmapuri S/C

765 kV Tuticorin PS – Dharmapuri PS D/C

400 kV New Somanahalli- Salem D/C

400 kV Tirunelveli-Edamon- Muvaptuzha(Kochi) D/C

400 kV Tirunelveli-Kanarpatty D/C

400 kV Kanarpatty-Kayathar

400 kV Trichur – Kozhikode D/C

It had also been highlighted that most of the transmission was required on priority.

12. UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH

TRANSMISSION NETWORK

Status update of the upcoming schemes in Southern Region for renewables as given

below is given at Annexure-XXI.


Uravakonda Wind – AP

Solar Power Park at Ghani/Panyam (1000 MW )Phase-I Works – AP

1000 MW Wind Power at Aspiri- AP

1500 MW NP Kunta Solar Project- AP

Kamuthi Solar (Max 100 MW injection)- TN

Samugarengapuram Wind (1800 MW existing + 300 MW) - TN

Green Energy Corridors:- Inter State Transmission Scheme (ISTS) - Part - A

LTA to Wind Generators in Tirunelveli Area - Tamil Nadu

Connectivity to Wind Generators in Coimbatore Area -Tamil Nadu

Connectivity to Wind Generators in Anantpur Area – AP

Renewables (KfW) Hindupur - AP

Renewables (KfW) Jammalamadugu - AP

Renewables (KfW) Uravakonda - AP

Renewables (KfW) 220 kV Interconnectivities - AP

Renewables (KfW) 132 kV Interconnectivities – AP

Renewables (KfW) Intra-state - Karnataka

Renewables (KfW) Phase I – Tamil Nadu

Tumkur Ultra Mega Solar Park (2000 MW) – Karnataka

13. FOLLOW UP ACTIONS ON THE RECOMMENDATIONS OF CENTRAL

ADVISORY COMMITTEE (CAC) SUB - COMMITTEE ON CONGESTION IN

TRANSMISSION

13.1. Hon’ble CERC had passed order (date of order: 5.8.2015) in Petition No.009/SM/2015,

in the matter of follow up actions with regard to recommendations of Central Advisory

Committee (CAC) Sub-Committee on Congestion in Transmission. Sub-Committee had

recommended measures to reduce congestion in transmission for which necessary

actions is to be taken by CEA, NRCE, CTU, POSOCO, POWERGRID, RPCs as well as

CERC. Commission had considered the report and accepted its recommendations

.Recommendations of the Committee with regard to the actions to be taken by various

agencies along with timelines was decided by the Commission.

13.2. In ROP dated 19.1.2016 in respect of Petition No.009/SM/2015, the following had been

stated:

‘The Commission observed that there is a need to institute a mechanism for monitoring of

the implementation of the recommendation of the CAC Sub-Committee on Congestion in

Transmission in accordance with the time line specified in the Commission`s order dated

5.8.2015. The Commission further observed that National Reliability Council (NRC) be

entrusted with the task of monitoring the implementation of the direction given in order

dated 5.8.2015 and submit periodical report to the Commission for information/further

direction. The Commission directed that an officer associated with NRC may be present

during the next date of hearing.’


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

14.1. Krishnapatnam UMPP (6x660 MW)

The following had been noted in Meetings of TCC/SRPC:

Hon’ble CERC had passed Orders on 04.08.2015 in respect of Petition No.

283/MP/2012. Relevant extracts reproduced below please:

“Therefore, the issue before the Hon`ble High Court and this Commission is the same

i.e. whether the change in the coal prices on account of promulgation of Indonesian

Regulations is an event of Force Majeure and Change in Law. Moreover, while the

petitioner is challenging the jurisdiction of the Commission to deal with the said

Force Majeure event before the Hon`ble High Court of Delhi, the petitioner is

invoking the jurisdiction of this Commission for a declaration that increase in coal

price on account of Indonesian Regulations is covered under Force Majeure or

Change in Law. In our view, the petitioner should either pursue the appeal before

the Hon`ble High Court or pursue the petition before this Commission. It is pertinent

to mention that despite committing before this Commission, the petitioner did not

take any effective steps to expedite the hearing before the Hon`ble High Court of

Delhi. Since the petitioner is pursuing the appeal before the High Court, we are of

the view that no useful purpose will be served by keeping the petition pending in the

Commission. Accordingly, we dispose of the petition, with liberty to the petitioner to

approach the Commission at the appropriate stage in accordance with law, if so

advised”

In the 27th TCC Meeting, PCKL had informed that the lead procurer and PCKL had

taken appropriate steps with their legal counsel to expedite hearing before Hon’ble

High Court of Delhi.

14.2. Cheyyur UMPP (4,000MW)

In the 27th

TCC Meeting, CTU had informed that this project had been identified

under ‘Plug and Play Mode’ and new bids would be invited during 2015-16.

14.3. Schedule of synchronizing/commissioning of the new projects of NTPC, NLC,

NPCIL, BHAVINI, Joint Venture & UMPP is furnished below:

Station Unit

Installed

Capacity

MW

Scheduled date of

synchronizing /

commissioning

Remarks

NTPC

Kayamkulam I, II,

III

1050/

1950

12th

Plan

Kudgi TPS

Stage-I

I,I,

III

3x800=

2400

Unit-I Synchronization

by March 2016.

CoD by January

2017.

Unit-II

synchronization by

October 2016. CoD

by March 2017.

One Narendra-Kudgi D/C line

declared deemed COD on

04.08.2015 by KTL (L&T infra

projects).


Unit–III synchronization by

March 2017. CoD

by July 2017.

Telangana STPP

Phase I

2x800

Pudimadaka -

AP

5x800 85% share to AP

NLC

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 St-I II 1000 Unit-II:

Synchronization by

April’ 2016.

BHAVINI

Kalpakkam

(PFBR)

I 500 September 2016

UMPP

Krishnapatnam 3960

(6x660)

APEPDCL and PCKL had taken

steps with their legal counsel to

expedite the hearing before

Honorable High Court of Delhi

Cheyyur 4000 MoP had identified the

UMPP under ‘Plug and Play

Mode’ and new bids would

be called in year 2015-16.

In the 116th OCC Meeting NTPC had informed that Kudgi Unit I was planned to be

synchronized during March 2016. Kudgi 400/220 kV ICT was scheduled to be

commissioned by March 2016

15. NEW PROJECTS OF STATE SECTOR & IPP

15.1. Updated status of new projects of State sector furnished below:

Sl

No.

Name of project Located

in

Capacity in

MW

Commissioning Schedule

/Remarks

1 Rayalaseema TPS ST-

IV

AP 1x600 CoD by Dec’ 2016

2 Dr. NTTPS,

Vijayawada

AP 1x800

3 Polaki AP 4000

4 Bellary TPS U-3 KAR 1x700 Synchronized to grid on

25.12.2015. CoD expected by

Feb’2016


Coal sync. By Dec.2015

5 Yermarus TPS KAR 2x800 Unit-I: Synchronization by Jan’

2016 and CoD by Feb’2016.

Unit II: CoD by May’ 2016.

6 Kakatiya TPP St.-II Telangan

a

1x600 Light up with Oil started on

07.12.2015 and first

synchronization on 15.12.2015.

7 Singareni Telangana 2x600 Unit I: CoD by April 2016

Unit II: CoD by June 2016

8 Manuguru PPP Telangana 4x270

9 Kothagudam TPS Phase

VII

Telangana 1x800

10 Damaracherla Telangana 2x600 +

4x800

15.2. Updated status of new projects of IPPs is furnished below:

Sl

No.

Name of project Located

in

Capacity

in MW

Commissioning Schedule /Remarks

1 Meenakshi PH-II AP 1x700 2016-17

Untied: 640 MW

2 East Coast Energy

Thermal

AP 2x660

2015-16

AP : 300 MW

3 Thermal Powertech.

(TPCIL) Unit-III

AP 1x660

CoD : 2016-17

4 NCC Krishnapattnam AP 2x660

Unit I : CoD by 2015-16

Unit II: Syn. by September 2016

AP : 500 MW (firmed up PPA to

be signed).

5 Hinduja NPCL, Vizag AP 2x520 Synchronized to grid& Full load

achieved on 27.12.2015

6 Coastal Energen Unit-II TN 1x600 First synchronized to grid on

28.12.2015

7 IL&FS

(ITPCL) Unit-II

TN 1x600

16. EMERGENCY RESTORATION SYSTEM (ERS)

16.1. Availability and proposed plan for development of ERS in Southern Region had been

noted in the 27th

Meeting of SRPC. As per requirement of ERS outlined in MoP letter

dated 05.12.2014, status update is given below please:

Transmission Utility

Requirement as per MoP

Existing Status/Remarks

APTRANSCO 3 Nos. ERS I – Inspection completed on

18.08.2015 (for Nellore). ERS II –

Inspection completed on 22.11.2015 and

expected by February 2016 (for Vizag.)


For 3rd

ERS, tendering process had been

initiated.

TSTRANSCO 1 No. Procuring 1 No. of ERS and it would take

10-12 months.

KPTCL 2 No. 2 Nos.

KSEBL 1 No. 1 No. was being taken up by their

transmission wing and was put up for

Budgetary approval.

TANTRANSCO 2 Nos Demo had been given by Vendor.

Estimate to be prepared and would be

submitted to Board.

PED Nil

PGCIL 4 Nos. ( 2 Nos

additional)

2 Nos (SR I

& SR II was

having 1 No.

each)

SR I & II, PGCIL informed that work has

been awarded to procure ERS at 400 kV

level. One of ERS was planned at

Somanahalli and Vijayawada each.

In the 116th OCC Meeting, APTRANSCO had informed that one ERS has been

received on 22nd

December 2015 and has been located at Nellore. Training was being

imparted. The second ERS would be delivered by end February 2016.

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

17.1. Status of implementation of Bus / Line Reactors / Dynamic Compensation approved in

the Standing Committee / SRPC pending for commissioning by the SR constituents is

furnished below please:

Entity Bus Name Status REMARKS

KPCL Raichur TPS Commissioned on

01.12.2015

As identified in the 22nd

Standing Committee Meeting

on Power System Planning of

SR and as approved in the 4th

SRPC Meeting held on 7th

June

2007 KPTCL

Hoody By December 2015

Nelamangala By December 2015

Talaguppa Commissioned on

26.11.2015

Entity Bus Name

Capacity

in

MVAR

Approved

in Type Remarks

PGCIL Vijayawada 2x125

20th

SRPC/

34th

SC

Bus LOA placed

Would be

Commission


17.2. Dynamic Compensation (Approved in 36th

SC)

Entity Bus Name

SC

MVA

GVA /

KA

Dynamic

Compensation

(STATCOM)

Mechanically

Switched

Compensation

(MVAR)

Remarks

Nagarjuna Sagar 125

21st

SRPC/

34th

SC

Bus

ed

progressivel

y by

September

2016 Narendra 125

21st

SRPC/

34th

SC

Bus

Hyderabad 125 21st SRPC

Gooty 125

22nd

SRPC /

36th

SC

Bus

Hassan 125

36th

SC

Bus

Khammam 125 Bus

Kudgi PG 125 Bus

Trivandrum 125 Bus

Nellore (Existing) 125 Bus

Yelahanka 2x63 Bus

Nellore PS on NPS-

Gooty Line

2x63

(37th

SC) Line

Kudgi PG–Tumkur

D/C at each end 4x63 Line

APTRANSCO

Vemagiri 80

21st

SRPC/

34th

SC

Bus By June

2015

Vemagiri 125

36th

SC

Bus By March

2016

Kurnool 125 Bus Tender to

be called

Kalpakka 125 Bus By April

2016

TSTRANSCO

Mamidipalli 125

36th

SC

Bus

By June

2016

Gajwel 125 Bus

Sankarapalli 125 Bus

Mehboob Nagar 125 Bus

NPCIL Kaiga 2 x125

Bus

Process

started

Expected

in one and

half year

after

award.


Reactor Capacitor

PGCIL

Hyderabad 18.4/

26.5

+ 200 MVAR 2x125 1x125

Under

Tendering

Udumalpet 19.4/

28.0

+ 200 MVAR 2x125 1x125

Trichy 12.5/

18.0

+ 200 MVAR 2x125 1x125

17.3. Possibility of Reactor at Srisailam

17.3.1. A Joint Meeting with CEA, TSGENCO & TSTRANSCO had been held on

16.04.2015. It was noted that reactor at Sattenapalli or Kurnool had been proposed

instead of Srisailam due to space constraint.

17.3.2. In the 114th

OCC Meeting, TSTRANSCO had informed that vide letter dated

06.10.2015 it had taken up the issue with CEA. TSTRANSCO had requested that CEA

may kindly arrange to conduct a comprehensive feasibility study including load flow

studies, reactive power compensation etc. on installation of reactors at Srisailam and at

other ends of connected lines. Necessary information, if any, required from TSGENCO

would be furnished for carrying out the above study.

17.4. Reactive Power Planning

In the 4th

NPC meeting held on 10.12.2015 (MoM dated 01.01.2016), the following had

been noted:

All States to carry out reactive power planning not only at transmission level

but also at distribution level and prepare schemes to maintain voltage profile

as per relevant Regulations / Standards.

NPC agreed that states should adopt a proactive approach in the matter of

reactive power planning, and that the provisions regarding reactive power

planning similar to those mandated in the IEGC for the CTU should be

included in the respective State Grid codes. It was decided that RPCs would

follow up the matter further with the states.


18. ISSUES IN RESPECT OF CONGESTION CHARGES

18.1. In the 28th

SRPC Meeting it had been agreed as a special case for waiving off of

congestion charges for the first week of June 2015 in view of the fact that notice

/messages had not been timely received by a number of entities. SRLDC had stated that

balance amount had already been transferred to PSDF. It was hence agreed that if

charges are refunded by the receivable entity, it could be given back to the entities (who

had made payment for that week).Else, payments could only be adjusted in the future

congestion accounts.

18.2. Subsequently SRPC vide letter dated 01.01.2016 (Annexure-XXII) had withdrawn the

account issued on 16.06.2015.

19. ADDITIONAL SUPPORT THROUGH 110 KV PARASALA – KUZHITURA

FEEDER

19.1. KSEBL vide letter dated 09.12.2015 (Annexure-XXIII) had requested TANTRANSCO

for drawing up to 250 A on 110 kV level from Kuzhiturai Substation as interim measure

till the 220 kV Substation at Kattakkada is commissioned. It was mentioned that for

drawing about 250A, reconductoring in some stretches and replacement/renovation of

some of the towers are necessary which would take a period of about 2 months to

complete. It was also requested by KSEBL that an early confirmation on facilitating

drawing up to 250A from Kuzhithurai may kindly be communicated so as to commence

line strengthening works as early as possible. It was noted that line strengthening work

carried out by KSEBL would be mutually beneficial in the long run.

19.2. The issue had been deliberated in 115th

OCCM held on 08.01.2016 in which

TANTRANSCO had stated that the line was already loaded up to .maximum and even

for 20 MW flow, the same was getting tripped on overload. Increasing drawal at

Parasala end would overload the feeder feeding from SR Pudur to Kuzhithurai S/S.

19.3. Vide letter dated 07.01.2016, Chief Engineer (GO), TANTRANSCO had communicated

to KSEBL in this regard (Annexure-XXIV).

20. OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS

20.1. TANTRANSCO vide letter dated 09.12.2015 had informed that they had received Rs

98,64,551/- from Maharashtra State Electricity Distribution Co. Ltd

(MAHAVITARAN/MSEDCL) towards, energy transaction for the period from August

1999 to December 2002 (Annexure-XXV).

20.2. MAHAVITRAN vide letter dated 20.11.2015 (Annexure-XXVI).had informed that


following payments had been made to SR constituents.

S.NO Constituent Bill amt in (`) Pmt. Details Payment amt in

(`)

1 KSEB 1,19,61,444/- 111 – 12.10.15 1,19,61,444/-

2 Puducherry 27,39,427/- 112 – 12.10.15 27,39,427/-

3 Tamilnadu 98,64,551/- 109 – 12.10.15 98,64,551/-

4 KPTCL 12,09,650/- 110 – 12.10.15 12,09,650/-

Total 2,57,75,072/- 2,57,75,072/-

20.3. Pending payments between WR & SR Constituents as on 09.12.2015 are as follows:

ANDHRAPRADESH / TELANGANA

RECEIVABLE FROM (Rs) PAYABLE TO (Rs)

MPPMCL 1,21,76,270 NIL

KARNATAKA


MPPMCL 13,27,208 CSPDCL 73,72,176

GUVNL 9,40,320

KERALA


MSEDCL 1,19,61,444*

NIL MPPMCL 1,21,47,260

CSPDCL 7,05,279

GUVNL 4,98,019

TAMIL NADU


MPPMCL 1,17,17,268 CSPDCL 92,77,878

PUDUCHERRY



MSEDCL 27,39,427* NIL

GUVNL 1,02, 721

Payable by PGCIL (WRTS / SRTS)

State/UT Amount (Rs.) Received Balance to

receive (Rs.)

Andhra Pradesh/

Telangana

47,05,447 3,69,848 4,335,599

Karnataka 49,79,733 3,91,407 45,88,326

Kerala 27,58,402 2,16,811 25,41,591

Tamil Nadu 47,21,994 3,71.149 43,50,845

Puducherry 9,24,035 72,629 8,51,406

Total 1,80,89,611 14,21,844 1,66,67,767

* confirmation is pending from the concerned utility that payment has been

received from MAHAVITRAN (MSEDCL).

20.4. KSEBL had confirmed receipt of payment while Puducherry and KPTCL had yet to

confirm receipt of payment from MAHAVITRAN (MSEDCL).

21. SRPC CERTIFICATION TO CLAIM ADDITIONAL RoE

21.1. PGCIL vide letters dated 19.01.2016 & 02.02.2016 (Annexure-XXVII) have requested

SRPC certification to claim additional RoE in respect of the following assets:

Kurnool – Raichur 2nd

765KV S/C Line along with associated bays and equipment at

Kurnool and Raichur Substations under ISGS Krishnapatnam :It was stated that the

line has been put into commercial operation w.e.f. 21.06.2014 i.e. commissioned

1.35 months ahead of CERC completion schedule.

Kurnool(New) – Raichur 765KV S/C Line along with associated bays and

equipment at Kurnool and Raichur Substations under SRSS - XXII: It was stated that

the line has been put into commercial operation w.e.f 15.12.2015 i.e. commissioned

13.71 months ahead of CERC completion schedule.

Kurnool – Thiruvalam 765KV S/C Line along with associated bays and equipment at

Kurnool and Thiruvalam Substations under SRSS - XIX: It was stated that the line

has been put into commercial operation w.e.f 29.11.2014 i.e. commissioned 13.04

months ahead of CERC completion schedule.

Nellore – Kurnool 765KV D/C Line along with associated bays and equipment at

Nellore and Kurnool Substations under ISGS Krishnapatnam: It was stated that the

line has been put into commercial operation w.e.f 01.11.2014 i.e. commissioned 1

month ahead of CERC completion schedule.


21.2. In the 116th

OCC Meeting held on 10.02.2016, the forum had recommended for

Additional RoE.

22. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION

22.1. Automatic Demand Management Schemes

22.1.1. In line with clause 5.4.2 (d) of IEGC, Automatic Demand Management Scheme was to

have been provided by all constituents by 1stJanuary 2011.SRLDC & SRPC Secretariat

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

Regulatory requirements.

22.1.2. In 28th

SRPC Meeting, the following had been noted:

The AMDS logic was finalized as OD >250 MW or 20 % of Schedule, whichever

lower, for 15 minutes when frequency < 49.8 Hz. This setting (49.8 Hz) would be

reviewed for subsequent enhancement to 49.9 Hz. All states would implement this

revised logic by 1st November 2015 without linking to SCADA activities.

However, SRLDC maintained that frequency setting for ADMS scheme should be

49.9 Hz in accordance with IEGC Regulations.

22.1.3. In the OCC Meetings it had been noted that all entities except TN had implemented the

ADMS. Issues like enhancement of quantum and logic were being discussed in the

OCCM. KPTCL was yet to implement the revised logic.

22.1.4. It is now recommended to change the set points to 49.9 Hz in line with IEGC

provisions.

22.1.5. In the 116th OCC Meeting (10.02.2016) the following was noted:

AP: 100 MW additional loads (total 250 MW) had been identified for ADMS and

would be implemented

TN: Mock test had been conducted on 07.02.2016 and ADMS (650 MW) would be

commissioned by 15.02.2016.

22.2. UFR and df/dt reliefs

22.2.1. All States have implemented AUFR and df/dt schemes fully. Details of recommended

and implemented quantum wrt AUFR & df/dt schemes by constituents are shown in

the Table below:


Sl.

No

AUFR and df/dt stages

AP TS KAR KER T N Pudu

Reco

mm

end

ed

Imp

lemen

ted

Reco

mm

end

ed

Imp

lemen

ted

Reco

mm

end

ed

Imp

lemen

ted

Reco

mm

end

ed

Imp

lemen

ted

Reco

mm

end

ed

Imp

lemen

ted

Reco

mm

end

ed

Implem

ented

AUFR Average MW

1 Stage-I (49.2 Hz) 392 392 417 419 576 578 204 214 740 804 21 21

2 Stage-I (49.0 Hz) 393 393 419 420 578 578 205 217 744 808 21 22

3 Stage-I (48.8 Hz) 398 398 424 426 586 593 208 212 753 867 21 25

4 Stage-I (48.6 Hz) 399 399 426 431 588 593 209 211 756 867 22 24

AUFR Total 1582 1582 1686 1696 2328 2342 826 854 2993 3346 85 92

1 df/dt stage-I (at 49.5 Hz

& 0.2 Hz/sec fall of

frequency) 345 345 367 368 474 483 172 178 624 626 18 12

2 df/dt stage-II (at 49.3

Hz & 0.3 Hz/sec fall of

frequency) 855 855 912 914 737 734 175 175 559 572 0 6

df/dt Total 1200 1200 1279 1282 1211 1217 347 353 1183 1198 18 18

22.2.2. Hon/ble CERC vide Order dated 27.11.2015 in respect of Petition No. 60/MP/2014 had

directed KSEBL to file a confirmation report regarding completion of AUFR & df/dt

relays mapped to SCADA system of KSEBL to SRPC by 31.12.2015 . In the Order

SRPC Secretariat had also been directed to submit status of Implementation of

mapping of AUFR & df/dt relays with SCADA system in respect of all constituents of

SR by 31.01.2016.

22.2.3. SRPC vide letter dated 29.01.2016 (Annexure-XXVIII) had submitted status report

duly certified by SRLDC and SRPC wrt implementation of SCADA mapping of all

constituents to Hon’ble CERC. SCADA mapping confirmation report of KSEBL had

also been submitted to Hon’ble CERC. Status of SCADA mapping details as submitted

to Hon’ble CERC is given below please:

Figures in MW

Recommend

ed quantum

(AUFR+df/dt)

Implemented

quantum

(AUFR+df/dt)

SCADA

monitorable at

SRLDC

% Monitorable

wrt

Recommended

quantum

AP 2782 2782 1169 42%

TS 2965 2978 1898 64%

KAR 3539 3559 3557 101%

KER 1173 1207 1184 101%


TN 4176 4544 3849 92%

Pudu 103 116 116 113%

SR 14738 15186 11773 80%

22.2.4. In the 4th

NPC meeting held on 10.12.2015 (MoM dated 01.01.2016), the following

had been noted:

Ensuring proper functioning of Under Frequency Relay (UFRs) and df/dt

relays

…………. at least 20% of the under frequency relays installed in the respective

regions should be physically inspected by respective RPCs in each year besides

self-certification by the STUs. Regarding self-certification by the STUs

regarding healthiness of the UFRs as per checklist proposed by NRPC, Other

RPCs were requested to forward their comments / suggestions to NPC for

evolving a uniform procedure across the states at the next meeting.

Automatic Under Frequency Load Shedding (AUFLS) scheme:

NPC expressed satisfaction that barring a few states, the revised AUFLS scheme

had been implemented by the states in the country. It was decided that the RPCs

would take up the matter of implementation of the scheme with the states which

had not so far implemented the same and inform the progress at the next

meeting.

Review settings of df/dt relays and UFR based automatic load shedding

schemes

Review of df/dt relays:

NPC opined that in the event of a sudden loss of generation or any grid

disturbance, the rate of fall of frequency would vary from one location to another,

and it would also vary from one point of time to another at a particular location

depending upon the distance from the location of the fault. Therefore, there could

be no uniform setting of df/dt relays in different regions. In view of this, NPC

decided that settings would be determined by each RPC separately after detailed

study of load and generation balance in different areas of the region and

communicate the same to the Committee for ratification.

Review of Automatic Under-Frequency relay based Load-shedding Scheme

(AUFLS)

NPC decided to maintain status quo in respect of AUFLS. It was also agreed by

the RPCs to initiate the process of mapping of feeders covered under AUFLS

scheme like SRPC with a view to ensuring proper implementation of the scheme

and also have a real time assessment of load-relief likely to be available under the

scheme if it operated.

22.3. UV Relay Installation at Low Voltage Nodes

22.3.1. The following had been noted in various Meetings:

KPTCL: Automated UV relay scheme was under review.


SRLDC had stated that Bangalore voltage was very less for around 20 % of time

during December 2015 and touched 380 kV also. KPTCL was requested to expedite

the automated UV relay implementation.

KSEBL: Revised set points had been implemented both at Palakkad and Thrissur.

TANTRANSCO: TN to provide relays and cable terminations to PGCIL to extend

under voltage conditions (dv/dt or V+t to Myvadi 230 kV RTU) of Myvadi 400 kV

Bus for the implementation of UV relay scheme at Udumalpet. This was expected to

be completed by June 2016. PGCIL informed that they had extended the signal to

Myvadi substation as desired by TN and relay procurement and other works were

under TANTRANSCO’s scope.

It was noted that in the 27th

TCC Meeting held on 9th

October 2015, TANTRANSCO

had committed that they would implement UV relays by December 2015. No action

plan had been given by TANTRANSCO. Need for implementation of the same on

urgent basis was emphasized. TANTRANSCO had been requested that this issue may

kindly be taken up with their Higher Management.

22.3.2. In the 116th

OCC Meeting (10.02.2016) the following was noted:

KAR: It was noted that UV Relay had operated on 12.01.2016. KPTCL stated that

Automated UV Scheme was in place.

TN: Would be commissioned by end of February 2016

22.4. Restricted Governor Mode of Operation (RGMO)/FGMO of Generating Units

22.4.1. RGMO response was being analyzed in the OCC meetings and inadequate response

was an area of concern and there was no noticeable improvement. SLDCs were to

analyze RGMO instances posted by SRLDC for the generators in their control area and

initiate suitable action as per orders in respect of 84/MP/2015. Inadequate Response

was to be taken up with SERC (Petition No.302/MP/2013).

22.4.2. It was noted that Hinduja NPCL (IPP) was yet to confirm that RGMO was meeting

IEGC requirements. In Bellary Unit-III (KPCL), & Kakatiya Stage-II Unit

(TSGENCO), RGMO was implemented and enabled. RGMO was not implemented in

Mettur Stage-III which was in violation with IEGC provisions.

22.4.3. Regarding extension of RGMO status point to SRLDC/SLDC, the following had been

noted in the Meetings of OCC:

APTRANSCO: Upper Sileru (Cable problems) & Machkund (RTU problem)

stations. Krishnapatanam Unit -1 have implemented RGMO and extended the

status point to SLDC. It was informed that RGMO implementation and extending

the status point of Unit-2 will be completed by 25th

Dec 2015.

TSTRANSCO: Status points were done for Thermal units. Status on Hydro units

was to be furnished.

TANTRANSCO: MTPS- I & II, MTPS St-III & Hydro stations were pending


KPCL: Taking up with the Management and they would extend the status point of

all thermal units except Unit 4 of RTPS as it was under Japanese OEM. Status

points of all hydro units like Almathy, Kadra & Gerusoppa HEPs to SLDC had

been made available but yet to be configured to SLDC.

22.4.4. Hon’ble CERC had issued Order on 23.10.2015 in respect of Petition No.

302/MP/2013 and the following are the highlights:

Oil support, if required, for grid security needs to be resorted.

Taking out of RGMO/FGMO with MI during technical minimum condition or for

any other reason is not desirable, as it would jeopardize grid security.

RLDCs/SLDCs have inherent powers to restrict the schedule corresponding to 100

% if installed capacity without vide valve open condition even at part loads

ensuring primary governor response at all stages. It was reiterated that unit should

not be scheduled beyond 100 % of MCR rating.

SLDCs through their respective SERCs may initiate action against Generators

which are not adhering to Regulation.

It was mentioned in the Order that irrigation based project would be exempted

from implementation of RGMO/FGMO.

22.4.5. SRLDC had pointed out that in view of CERC Order w.r.t Petition No.302/MP/2013,

SLDCs need to restrict the state generators schedule suitably. They would take

normative auxiliary consumption from REA of SRPC and would apply it to on bar

installed capacity. In case DC being declared was less due to some coal/technical

constraints it was generators responsibility to accommodate 5% margin for RGMO

response. It was emphasized that wide valve operation should not be envisaged during

DC declaration.

22.4.6. In the 116th

OCC meeting, Mettur TPS St- III confirmed that FGMO with MI was in

place and RGMO was under consideration.

22.4.7. KSEBL vide letter dated 06.02.2016 had raised certain issues regarding curtailment

of schedule without change in DC. In 116th

OCC Meeting, the following

methodology was agreed regarding curtailment of schedule to ensure suitable margins

for RGMO/FGMO:

ISGS generators would also furnish the ex- bus capability to ensure margins

for RGMO/FGMO.

Schedules would be restricted to the above ex-bus capability.

Revisions in schedules and URS surrenders/allocation methodology would be

furnished by SRLDC


22.5. Low Voltage Ride Through (LVRT)/Provisions of CEA Regulations in respect of

Renewables

Hon’ble Commission had issued Order dated 05.01.2016 in respect of Petition

420/MP/2014 and number of actionable points had been directed for different Utilities.

A Meeting in this regard was held at SRPC, Bangalore on 05.02.2016 (record notes

available in SRPC website). All concerned utilities are kindly requested to take

necessary action as enumerated in the record notes to ensure compliance of CERC Order

as well as CEA Regulations.

22.6. Demand Estimation for Operational Purpose (Clause 5.3 of IEGC)

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

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

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

19th

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

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

Eastern Region to forecast their demand and make adequate arrangements to

avoid dependence on Unscheduled Interchange for meeting their demand or for

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

Load Forecasting tool meeting the regulatory requirement yet to be developed by all the

utilities.SRLDC/SRPC Secretariat had expressed concern that Regulatory requirements

had not been met since the scheme was to have been in place by 01.01.2011.

22.7. Sudden Change in Demand/Frequency Excursion

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

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

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

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

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

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

Regulations is not violated.

22.7.2. SRLDC/SRPC Secretariat had expressed concern that Regulatory provisions were not

being fully met and requested for necessary compliance.

22.8. Arranging of interruptible loads in four groups

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

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

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


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

any SPS Scheme. These loads are to be grouped in such a manner that there was no

overlapping between different groups of loads.

22.8.2. Existing schemes were not meeting the Regulatory requirement fully and further action

was required in this regard please.

22.9. PSS Tuning

22.9.1. 2nd

Meeting of PSS tuning was held on 30.10.2015 and many actionable points were to

be carried out by Generators of SR. Many generators had not furnished information in

this regard as requested. SRPC vide letter 22.01.2016 (Annexure-XXIX) had

communicated that all generators/utilities may kindly furnish PSS details and Step

Response Test Reports in the specified format at the earliest.

22.9.2. It is kindly requested that necessary action may kindly be taken as finalized in the 2nd

meeting of PSS.

22.9.3. In 4th

NPC meeting held on 10.12.2015 (MoM dated 1.1.2016), it was noted that the

Enquiry Committee constituted by GOI to enquire into grid disturbances of July 2012

had recommended proper tuning of electronic devices and PSS of generators.

Accordingly, NRPC submitted their recommended procedure to NPC for comments

/adoption by other RPCs so as to bring uniformity across all regions. It was agreed that

other RPCs would examine the proposal of NRPC and revert back in the next NPC

Meeting.

22.10. Scheduling of Simhadri STPS Stage-I by SRLDC

APTRANSCO had filed a Petition in CERC in this regard and the petition was admitted

on 7th

January 2016. A hearing in this regard is also scheduled on 16th

February 2016.

22.11. SPS related Issues

22.11.1. Implementation of additional loads for SPSs

22.11.1.1. The following was deliberated in earlier Meetings:

Mock Testing of signal extension w.r.t TANTRANSCO, KSEBL & KPTCL had

been carried out on 13.10.2015 for additional requirement of SPS loads of 1,500

MW as per NLDC and found successful.

TSTRANSCO had identified loads of 875 MW under Veltoor, 400/220 kV Gajwel

S/S, 220 kV Budidampadu S/S and 220 kV RSS S/S. All DTPCs had been

installed in TSTRANSCO identified substations. PGCIL needed to extend signal

from Kolar to TS DTPCs.


22.11.1.2. Unit II of Kudankulam was expected by April 2016 and all constituents thus need to

identify feeders for the quantum envisaged as given below:

22.11.2. Modification in SPS of Raichur-Sholapur

22.11.2.1. It was noted that NLDC vide letter dated 23.12.2015 (Annexure-XXX) had

furnished revision in SPS settings subsequent to the commissioning of 765 kV

Kolhapur-Kudgi D/C line of Powergrid. KSEBL vide letter dated 07.01.2016 had

raised certain observations on SPS settings and stated that being an important issue

implementation could be considered only after detailed discussion. SRPC vide letter

dated 07.01.2016 had brought to attention of NLDC the views of Kerala.

22.11.2.2. A Meeting in this regard is scheduled to be held on 19th

February 2016.

22.11.3. Non Operation of Raichur-Sholapur SPS

22.11.3.1. NLDC vide letter dated 5th

January 2016 (Annexure-XXXI) had expressed concern

on the following issues regarding SPS scheme for Raichur-Sholapur D/C lines which

required urgent attention in terms of root cause analysis and taking necessary

actions:

I. Non – Operation of SPS on 2nd

January 2016

II. Revision in SPS settings subsequent to the increased TTC/ATC and

operationalized LTA/MTOA.

Trip

Signal AP KAR KER TN TS PUDU SR SPS

KKNPP 116 174 91 315 132 20 848

Loads to be identified & implemented by March 2016


22.11.3.2. SRPC vide letter dated 07.01.2016 (Annexure-XXXII) had requested Powergrid

SRTS I & SRTS II that reasons for non-operation of SPS may be kindly examined

and needful corrective action taken to ensure healthiness of SPS at all times.

22.11.4. Udumalpet - Palakkad SPS

22.11.4.1. SPS for Udumalpet-Palakkad lines was discussed in a Special Meeting held on

03.02.2016 (Minutes enclosed as Annexure-XXXIII). The SPS would be reviewed

after commissioning of Tirunelveli-Kochi Line.

22.11.4.2. KSEBL/PGCIL are requested to kindly initiate necessary action.

22.11.5. SPS Maintenance Protocol

22.11.5.1. In the 28th

SRPC meeting, SPS Maintenance Protocol to be implemented by PGCIL

was agreed. In the OCC Meetings, PGCIL had informed that Management approval

had been taken and work would be awarded soon.

22.12. Instantaneous Scheme for Sudden Withdrawal of Wind

22.12.1. In the Special Meeting held at Chennai on 20th

July 2015. TANTRANSCO had

informed that their P & C wing was taking up the above scheme and it would be in

place by 31st August 2015. In 27

th TCC meeting, TANTRANSCO had informed that

the scheme would be implemented by December 2015. In 115th

OCC meeting,

TANTRANSCO had stated that the scheme would be implemented by June 2016.

22.12.2. Hon’ble CERC in its Order dated 05.01.2016 on Petition No. 420/MP/2014 had stated

“In our view TANTRANSCO has failed to comply with the Commission's direction

given in order dated 22.2.2014 in Petition No. 120/MP/2011. Accordingly, we direct

SLDC, Tamil Nadu to explain the reasons, on affidavit, by 29.1.2016 as to why action

under Section 142 of the Act should not be initiated against it for non-compliance with

the provisions of the Grid Code and order of the Commission.”

22.13. Energy Generation data Management from Renewable Energy Sources

The following had been noted in earlier Meetings:

TANGEDCO had informed that a comprehensive scheme from the Energy Meters

along with AMR was under implementation. Scheme covered 4,500 existing

Energy Meters along with 8,500 new Energy Meters.

On a query it had been confirmed that Real Time Data (2-4 seconds) would also

be available at SLDCs. The scheme was being planned through GPRS and a

number of service providers were covered. This would improve the visibility of

wind generation significantly and assist in judicious decision making by the

operators at SLDC.


In the 27th

TCC meeting, TANGEDCO had informed that the comprehensive

scheme of Energy Meters along with AMRs would be in place by February 2016.

22.14. Pending issues of KKNPP

22.14.1. Need for additional reactor at KKNPP switch yard

NPCIL had informed that KKNPP unit would absorb 150 MVAR against 100

MVAR presently.

NPCIL had approached CTU regarding study for need for additional reactor.

As agreed in the 28th

SRPC Meeting, a Special Meeting was conducted at Bengaluru

on 20th

October 2015 (Minutes available on SRPC website) .The following was noted:

CTU representative stated that it was desirable that any additionally required

reactor come at a location that is close to source of VAR generation.

It was decided that KKNPP would take suitable measures to ensure that no VAR

injection takes place (from LV side) at voltages greater than 400 kV.

22.14.2. Implementation of auto reclose with 1½ breaker scheme

In the Special Meeting held on 20.10.2015, it was decided that KKNPP would come

up with suitable action plan to provide A/R on 400 kV KKNPP – Madurai line.

In the 115th

OCC Meeting, KKNPP informed that the response from Corporate was

awaited.

22.14.3. Pending SCADA inputs to SRLDC

KKNPP had informed that tenders had been opened and SCADA inputs would be

provided by February 2016.

In the 115th

OCC Meeting, KKNPP had informed that out of 13 pending SCADA

points, 11 points had been extended up to RTU.


22.15. UN-REQUISITIONED POWER

22.15.1. In the 113th

OCC Meeting SRLDC had informed that as per CERC Order dated

05.10.2015 on Petition No. 310/MP/2014 they would implement a new methodology

for URS allocation from 1st December 2015 onwards. A Special Meeting was held on

20.11.2015 (MoM available at SRPC website) for further deliberations on this issue.

22.15.2. SRPC vide letter dated 03.12.2015 (Annexure-XXXIV) had submitted

implementation difficulties in respect of Hon’ble CERC Order dated 05.10.2015 on

Petition No. 310/MP/2014. It had been requested that issues may kindly be arranged to

be examined and scheduling of URS Power may kindly be continued by

RLDC/POSOCO for improved utilization. Subsequently Hon’ble CERC had brought

out Order dated 18.12.2015 on Petition No. 16/SM/2015.

22.15.3. Extracts of CERC Order dated 18.12.2015 on Petition No. 16/SM/2015

Quote

3 Considering importance of the issues highlighted by the Member Secretary, SRPC,

the Commission is of the view that the matter needs to be heard at length with the

involvement of NLDC, SRLDC, SRPCs, ISGSs in Southern Region and the

Beneficiaries of the Southern Region.

4 Accordingly, it is directed that all concerned may file their views on affidavit on

the issues highlighted by Member Secretary, SRPC by 30th

December 2015.The

matter will be heard by the Commission on 05.01.2016. It is also directed that

RPCs / RLDCs/ISGs/ Beneficiaries of ISGSs of the other regions are also at

liberty to participate in the process dings of the Commission.

5. It is further directed that pending issue of clarification by the Commission as may

be considered necessary; RLDCs shall continue to schedule the URS Power in

accordance with our directions in order dated 05.10.2015.

Unquote

22.15.4. Hearing on the Petition was held on 05.01.2016. ROP dated 11.01.2016 is enclosed at

Annexure-XXXV and the extracts are reproduced here:

Quote

7. After hearing the learned counsel and the representatives of the parties, the

Commission observed that while SPL and CGPL do not have any difficulty in

scheduling of URS power in accordance with the direction of the Commission dated

5.10.2015, the Central Generating Stations and their beneficiaries have expressed

their difficulties in arranging consents of the surrendering beneficiary (ies) and the

requesting beneficiary (ies) for scheduling of URS power for each revision of

schedule. The Commission further observed that the Central Generating Stations and

their beneficiaries do not appear to have any difficulty in giving standing

unconditional consents with regard to scheduling of URS power. The Commission


directed that in modification of the direction in para 5 of the order dated 5.10.2015

and pending final decision on the issue, the following procedure shall be followed:

Where both the generating station and its beneficiaries (surrendering and requesting

beneficiaries) give their standing consents in writing to RLDC that the decision of the

concerned RLDC will be binding on them with regard to scheduling and dispatch of

URS power, the concerned RLDC shall schedule such URS power to the requesting

beneficiaries in relative proportion to the quantum requested by them. In other cases,

RLDCs shall schedule URS power on the basis of the consents submitted by the

generating stations in terms of the order dated 5.10.2015.

8. The Commission directed the respondents to file their replies by 22.1.2016, if already

not filed. The Commission directed that due date for filing the replies should be

strictly complied with. No extension shall be granted on that account.

9. The petition shall be listed for hearing on 23.02.2016.

Unquote

22.16. PROLONGED OUTAGES

22.16.1. In the 115th

OCCM Meeting held on 08.01.2016, the criteria for putting generating

units/Transmission elements under prolonged outage criteria was finalized:

In case of Annual Maintenance:

i. Generating units - Revival beyond five days of scheduled period.

ii. Transmission elements - Revival beyond two days of scheduled period

In case of forced outages:

i. Generating units - Revival beyond five days of tripping.

ii. Transmission elements - Revival beyond two days of tripping

22.17. Treatment of Bilateral short term and collective transaction in case of grid

disturbances

22.17.1. In the 4th

NPC meeting held on 10.12.2015(MoM dated 1.1.2016), the following was

noted:

Committee felt that the matter be first deliberated threadbare among the officers

of RPCs, who deal with the work of regional energy accounting, and a report /

recommendations thereon be put up by them during next meeting for

deliberations by the NPC.

Committee constituted a Working Group with following composition:

1. Director level representative from GM Division, CEA

2. SE/EE (Commercial) level representative from each RPC

3. AGM level representative from NLDC

4. Director (NPC) -Member Secretary/Convener

Working Group would examine & discuss possible options for Treatment of

Bilateral short term and collective transactions in case of grid disturbances and

submit its recommendations within two months for consideration of NPC at its

next meeting.

NPC requested CEA, RPCs and NLDC to nominate their representative for the


above Working Group.

22.18. Common Commercial Input data formats for all RPCs

22.18.1. In 4th

NPC meeting held on 10.12.2015 (MoM dated 1.1.2016),it was decided that the

committee formed for finalization of methodology for treatment of collective

transactions may also look into this issue and formulate uniform accounting

philosophy in Regional Energy Accounts being prepared by the RPCs.

22.19. Power swing blocking (PSB) setting in Distance relays:

22.19.1. In the 4th

NPC meeting held on 10.12.2015 (MoM dated 1.1.2016), NPC while

agreeing to NRPC's opinion to have a uniform PSB setting across all regions, decided

to maintain status quo in different regions and await the report of the Consultant

appointed for implementation of the recommendations of the 'Task Force for Power

System Analysis under contingencies' before further deliberations in the matter.

22.20. Other Issues requiring kind attention of TCC / SRPC

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

of SRPC merit kind attention:

a) Nominations for Study Group of SLDCs from APSLDC and TSSLDC are awaited.

In the 27th

TCC Meeting, APTRANSCO had informed that nominations would be

communicated after final bifurcation of staff. TSTRANSCO had informed that new

engineers would be recruited by Dec’2015 and subsequently, nominations would be

communicated.

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

award. In 115th

OCC Meeting, PGCIL had informed that Ist Stage PMUs have been

already supplied. PDCs are also supplied to AP and Telangana and installation was

being coordinated. 2nd Stage preparations were also underway. It was mentioned that

regular meetings had been conducted on monthly basis and a complete report would

be given to SRPC/RLDC. In the first stage, out of 76 PMUs to be installed, 62 had

been received and 52 had been installed.

c) Phase- I & Phase-II activities identified in Protection Audit need to be completed in

a time bound manner. Timelines given to Constituents vide various Orders of

Hon’ble CERC are given below please:


S.

N

o

Constituent CERC

Petition No.

/Date of

Order

Date for

completio

n of

Phase-I

activities

Date for

completio

n Phase-II

activities

Remarks

1 APTRANS

CO

95/MP/2015

Date of

Order :

27.4.2015

31.12.2015 31.12.2015 As the timelines given for

Phase-I and Phase-II works

have been completed,

APTRANSCO informed that

their management is in the

process of filing an

application before CERC for

obtaining further time

extension.

2 TSTRANS

CO

83/MP/2015

Date of

Order :

14.5.2015

31.10.2015 31.08.2016

3 KSEB 86/MP/2014

Date of

Order :

18.8.2015

31.12.2015

31.12.2015

31.3.2016

for R&M

works at

Idukki

HEP

As the timelines given for


have been completed, KSEB

informed that their

management is in the process

of filing an application before

CERC for obtaining further

time extension.

4 TANTRAN

SCO

374/MP/201

4

Date of

Order :

18.8.2015

30.6.2016 30.11.2016

5 NLC Date of

Order :

18.8.2015

NLC has sought time up to

31-12-2014 and 31-03-

2015 for completion of


respectively. As the

completion dates for Phase-

I and Phase-II of protection

audit remarks had already

been over, NLC was

directed to file a

confirmation report

regarding completion of

protection audit works for

Phase-I and Phase-II.

NLC informed that their

pending Phase-II works (2

no.) would be completed by

the second week of February,

2016.


APGECO and TSGENCO had informed that their managements are in the process

of obtaining further time extension.

From the above, it can be kindly seen that time extensions given to various

Constituents have been completed As such, following SR-Constituents, viz.,

APGENCO, APTRANSCO, TSGENCO, TSTRANSCO, KPCL, KPTCL, KSEB,

NPCIL (MAPS), NTPC (Ramagundam), PGCIL (SR-I & II), Spectrum PGL,

GMR-Vemagiri, GMR-Kakinada, APGPCL (Vijjeswaram Stage-I & Stage-II),

Konaseema GPL & LANCO-Kondapalli PL, have been requested to approach

Hon’ble CERC for obtaining further time extensions for the completion of their

pending protection audit works.

d) Reactive Power Planning including at distribution level needs to be submitted to

CEA with a copy to SRPC Secretariat. In earlier Meetings the following details

had been furnished by utilities:

Utility Reactive power Planning Voltage Level Remarks

APTRANSCO 32 x 7.5 MVAR

4 x 14.4 MVAR

33kV level

of 132/33 kV

SS

i.

APEPDCL Srikakulam : 5 x 2 MVAR

Vizianagaram : 5 x 2 MVAR

33/11 kV ii.

6 KPTCL Date of

Order :

18.8.2015

15.1.

2016

15.1.2016 As the timelines given for


have been completed,

KPTCL filed a separate

application before CERC on

07.01.2016 seeking time

extension up to 31.05.2017,

and the same is under

consideration by CERC.

7 KPCL Date of

Order :

18.8.2015

31.10

.2015

31.12.2015 KPCL informed that they

filed a Petition (No.

265/MP/2015) dated

29.10.2015 before Hon’ble

CERC praying to grant an

extension of time up to

30.12.2016 for completing

the Phases I and II activities.

The Commission in its ROP

dated26.11.2015 for the

Petition No.265/MP/2015 has

directed the KPCL to file

additional submission, if any,

by22.12.2015.

However, as no additional

submission is made by

KPCL, order of Hon’ble

CERC for the petition is

awaited.


Visakhapatnam : 5 x 2 MVAR

Rajahmundry : 10 x 2 MVAR

Eluru : 4 x 2 MVAR

:

level

APSPDCL April 2015 : 11x2MVAR

May 2015 : 16 x2 MVAR

June 2015 : 16 x2 MVAR

July 2015 : 1 x 2 MVAR

August 2015 : 2 x 2 MVAR

September 2015 : 2 X 2 MVAR

October 2015 : 0

November : 0

11 kV level

TSNPDCL 248*2 MVAR 81x1 MVAR and 80x2 MVAR

capacitor banks commissioned at

11 kV level. Orders had been

placed for 248x2 MVAR capacitor

banks and planned to be

commissioned by March 2016.

TSSPDCL 249 x2 MVAR 11 kV level LoA issued on 29.04.2015 for 221

x 2 MVAR capacitors at 11 kV

level with supply schedule of 4

month.

179 x5 MVAR 33 kV level Tendering under way.

Karnataka Bengaluru Tr. Zone:708.8 MVAR

Bagalkot Tr. Zone :258.1 MVAR

Hassan Tr. Zone :136.3 MVAR

Mysore Tr. Zone :60.9 MVAR

Gulbarga Tr. Zone :98.60 MVAR

Tumkur Tr. Zone :281.3 MVAR

Total of 1544 MVAR which were

planned to be implemented new

PO is placed. Bangalore zone

had ben retendered.

Kerala 15 MVAR 66kV level PO under Progress

TANGEDCO 34 x 2.4 MVAR 11 kV level Material had been received by

December 2015. Work will be

started from January 2015 and

may be commissioned by March

2016.

16 x 2.4 MVAR 22 kV level

7 x 24 MAVR 110 kV level

780 MVAR of capacitors at distribution level had been commissioned out of 1,005

MVAR capacitors planned. 2.4 MVAR capacitors at Somalapauram had been

commissioned on 30.06.2015.

e) Information regarding tripping details with relay indications needs to be furnished in

a timely manner.

f) Information regarding Cyber Security to be furnished to Chief Engineer, DPD, CEA,

New Delhi. Report on Physical Security, other Mock Drills for CMP, Mock Drill for

Black Start Restoration to be furnished to Chief Engineer, DMLF, CEA, New Delhi.

Copy of the report is to be sent to SRPC Secretariat by e-mail.

g) Procedure for restoration of remotely controlled sub stations of PGCIL along with the

contact no. of the person who would take care during emergency conditions needs to


be developed and furnished to SRLDC. The procedure was yet to be developed

despite follow-up.

h) Tap changing to recommended voltage level to be carried out at Kaiga GS, Upper

Sileru, Kothagudem TPS (Unit-2,3,4,5,6,7&8), Kadra, Kodasalli, Sharavathi Unit-9,

UPCL, JSWEL, Idukki, Lower Periyar Unit-1, Sabarigiri Unit-1,2&5, Tuticorin TPS,

Mettur Stage-III etc.

Issue regarding high voltages & additional reactor at KGS was discussed in the

Special Meeting held on 20.10.2015 and it was decided that NPCIL would

expedite the commissioning of 125 MVAR Bus Reactors. Further suitable

measures would be taken by Kaiga (U1 & U2) and Kaiga (U3 & U4) to ensure

that no VAR injection takes place (from LV side) at voltages greater than 220 kV

and 400 kV respectively. It was assured by Kaiga U3 & U4 for absorption up to

60 MVAR each from their Units. Kaiga Unit 1 & 2 also assured that absorption

form their units would be as per the corresponding capability curve.

In the OCC meetings, SRLDC/SRPC had expressed serious concern that GT taps

of KGS units were not being changed to recommended levels since long time

which was desirable from grid point of view. SRLDC stated that they would be

constrained to approach CERC if GT taps are not changed as recommended.

SRPC pointed out that it was to be noted that except Kaiga GS, all ISGS/CGS

stations had been changed as per recommendations.

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

lines at Kaiga (Kaiga –Narendra –II already enabled), 230 kV Neyveli – Villianur

lines , 230 kV Neyveli – Bahoor line, 230 kV BHAVINI – Siruseri, Chikkodi-

Mudshingi/Talangde & Ambewadi-Ponda lines Auto Reclose to be enabled for all

Inter Regional, Inter State and 220 kV& above lines

It was noted that the scheme of both the lines at Bhadrawati had been checked

for its correctness and functionality.SR I PGCIL had requested HVDC

Bhadravathi to confirm on the action plan for implementation of the A/R

scheme on Ramagundam- Chandrapur-D/C lines at Bhadrawati end.

SR-II, PGCIL had informed they were agreeable for PLCC up gradation at their

own cost and proposal had already been initiated and it would take 5-6 months

from completion. PLCC panels were ready and procurement of protection

couplers was going on. One spare protection coupler at Sriperumbudur could be

used and the works would be completed by end of January 2016

KGS had informed that A/R scheme was enabled for Kaiga-Narendra I & II line

and they would implement A/R feature for Kaiga-Guttur lines after stabilization

of lines.

TANTRANSCO had confirmed that A/R feature was available at Siruseri end. It

was noted that in the Meeting held at MAPS, Kalpakkam on 16th

December 2015

it was informed by BHAVINI that they will revert back in this regard.

Regarding Chikkodi- Mudshingi/Talangde lines KPTCL confirmed that at load

end (Chikkodi) A/R was not in service because of some relay replacement issues

which would be completed by month end. As soon as the relays were replaced

A/R would be energized at Chikkodi end by January 2016. It was noted that at

Mudshingi A/R was in service.

Regarding Ambewadi-Ponda KPTCL had informed that the R&M works were

going out for this line and the A/R would be covered in R&M works.


j) Operation of Nagarjuna Sagar in pump mode.

k) Restoration of 200MVA, 400/132 kV ICT-II at NTPC Ramagundam. TSTRANSCO

had offered 315MVA, 400/220 kV ICT for interim replacement as it was essential to

cater loads around RSS (Malyalapalli), Jagityal and Karimnagar areas.

l) TANTRANSCO had requested PGCIL to prioritize and expedite commissioning of

3rd

ICT at Kalvinthapattu. In the TCC Meeting, PGCIL had informed that they were

expediting 3rd

ICT at Kalvinthapattu and the same would be commissioned by January

2016. Associated bays would also get commissioned.

m) UPCL vide E-mail dated 05.01.2016 (Annexure-XXXVI) had expressed concern

regarding the increased tripping of 400 kV UPCL – Hassan and 220 kV UPCL –

Kemar lines severely hampering UPCL generation. The issue was deliberated in the

115th

OCC Meeting held on 08.01.2016 in which PGCIL had assured of improved

availability since they had taken over the maintenance from KPTCL.

n) 400 kV Kaiga-Guttur lines were out due to tower collapse in KPTCL portion of the

line. The lines were out from 29.11.2015. Ckt I was revived on 20.12.2015 while ckt

II was revived on 13.01.2016. It is a critical evacuation line for Kaiga. Important lines

need to be restored on priority.

o) SRLDC has taken up the task of Tap optimization of all ICTs in SR. As of now

SRLDC has done the tap optimization of 765/400kV, 400/200kV ICTs. To optimize

tap position of all 220/132kV and 230/110kV transformers, tap information (number

of taps, nominal tap position and present tap position) of all 220/132kV and

230/110kV transformers is required. It was requested by SRLDC that tap information

of all 220/110kV and 230/110kV transformers in the respective control areas may

kindly be provided as early as possible’

p) In the OCCM it was noted that NPCIL units would ensure DC close to actual and also

revise DC at the earliest during tripping of the units (within next block).

q) SRLDC had expressed concern on high loadings and N-1 violation of Nellore,

Arasur, Vemagiri, Somanahalli & Ramagundam ICTs. It was pointed out that there

was insufficient action in controlling the loading of ICTs leading to N-1 criteria

violation in compliance of Regulation 3.1f (8) of CEA (Grid Standards) Regulations

2010 and Regulation 3.5 a(i) of CERC Indian Electricity Grid Code Regulations

2010. High loading of Arasur and Nellore ICTs were referred to the Member

Secretary, SRPC under Clause 1.5 of IEGC 2010 vide SRLDC letters dated

30.12.2015.

r) SRLDC had informed that request for SCADA integration of new elements in ISTS

& Intra-STS network should be communicated at least one week in advance of COD

and last minute request would not be entertained. In GE system it could be integrated

online while in Alstom system shutdown was required (main and standby one at a

time). SRLDC had also emphasized that permission for synchronization of new units


would be given only after ensuring that their GT Tap positions were kept at a position

corresponding to 400 kV.

s) In the 114th

OCC Meeting it was noted that Puducherry vide letter dated 12.11.2015

had informed that they would explore the possibilities of diverting 23 MW quantum

of load relief from ADMS in operation at Puducherry to the newly proposed SPS

scheme at the first instance and accordingly co-ordinate with PGCIL for further

action. SR II, PGCIL had agreed that they would extend the signal up to Puducherry

SLDC.

t) Preparation of National Electricity Plan (NEP) is the responsibility entrusted to CEA

under Electricity Act, 2003. Under Section 3(4) of the Electricity Act, 2003, the

Authority shall prepare the NEP in accordance with the NEP and notify such plan in

five years after obtaining the approval of the Central Government. SRPC had

communicated to SR constituent/ states requesting information in the specified

formats vide letters dated 12.01.2016 and 25.01.2016.

u) In the 116th OCC Meeting the following was noted:

KGS: SRPC/SRLDC had expressed concern and stated that the taps were

required to be changed to the recommended value.

JSWEL: Agreed to change to 400 kV level. Unit 2 & 3 shut down was planned

shortly and after verifying the healthiness of OLTC the taps would be changed.

KAR SLDC was requested to ensure that the units come back with recommended

taps.

TTPS: TANTRANSCO informed that they would change the taps to

recommended, as and when opportunity arises.

Mettur Stage III : Agreed to change the Taps to 400 kV level. It was informed

that Bus reactor at Mettur Stage III switch yard was planned to be commissioned

by 31st March 2016.

In the 116th OCC meeting, it was agreed that constituents would take action to

ensure loading below 210 MVA (240 MVA emergency loading for short

duration) for 315 MVA ICTs. Loading up to 340 MVA only would be ensured

for 500 MVA ICTs. States would come up within 10 days about their short term

and long term plan to curtail the loadings.

TANTRANSCO and TSTRANSCO had informed that SPS for Arasur and

Ramagundam ICTs were being planned.

APTRANSCO had informed that 3rd ICT at Nellore was charged on 2nd

February 2016.


23. GRID STUDY COMMITTEE (GSC) (TASK-2) AUDIT PROGRESS DETAILS

23.1. As per the MoP order dated 16.07.2014, M/s Tractebel Engineering (TE) has been

appointed as Consultant to conduct the study/ analysis of National Grid. The terms of

reference of the Consultant are as follows:

a) To Review the status of implementation of the recommendations of the Enquiry

Committee (Task-1).

b) Carrying out actual protection audit check for 10% (76 nos.) of 762 substations across

the country to address the gaps, in consultation and collaboration with states and all

stakeholders as per present and future requirements (Task-2).

23.2. Task-1 for SR-Constituents was already completed by the first week of September,

2015. The draft report on Task-1 prepared by the Consultant was discussed in the third

Grid Study Committee (GSC) meeting held on 18th

November, 2015. Subsequently, the

feedback of the SR-Constituents was furnished to the Consultant by the last week of

November, 2015. The final report on TASK-1 by the Consultant is awaited.

23.3. Under Task-2, 15 Stations have been identified from SR for protection audit-check by

the Consultant. Various inputs (relating to relay settings, protection parameters, etc.)

sought by the Consultant in this regard have been collected from respective SR-

Constituents, and furnished to the Consultant. Based on the data furnished, Consultant is

to provide a set of recommended settings covering various relays for each of the 15

Stations, and to carry out physical protection audit of the same.

23.4. In this regard, 5 stations have already been audited during Dec 2015 – Jan 2016 as given

below:

Sl.No Name of the Station Period of Audit

1 Hosur SS of PGCIL (SR-II) 9th

-11th

December, 2015

2 Gazuwaka SS of PGCIL (SR-I) 28th

-30th

December, 2015

3 Alamathy SS of TANTRANSCO 4th

- 6th

January, 2016

4 Tirunelveli SS pf PGCIL (SR-II) 8th,

,9th

and 11th

January, 2016

5 Edamon SS of KSEB 18th

-20th

January, 2016

23.5. Out of the remaining 10 stations, 5 stations would be audited in Feb 2016 as given

below:

Sl.No Name of the Station Period of Audit

1 NLC TPS-II Station 8th

– 10th

February, 2016

2 Nelamangala SS of KPTCL 8th

– 10th

February, 2016

3 Gooty SS of PGCIL (SR-I) 12th

,13th

and 15th

February,

2016

4 Kurnool SS of APTRANSCO 16th

– 18th

February, 2016


5 Ramagundam Station of NTPC 18th

- 20th

February, 2016

23.6. The last set of 5 stations, namely Guttur, Kaiga, Raichur, Sharavathy and Kothagudem

would also be audited.

24. ISSUES RELATING TO PSDF FUNDING

24.1. Constituents had raised issue regarding LOAs placed before date of approval of scheme

by the Monitoring Committee for funding by PSDF. It had been stated that the subject

of sanction of funds from PSDF the works already taken up by the entities.

24.2. In this regard, Chairperson, SRPC had taken up this matter with Secretary (Power) vide

letter dated 21st May 2015.

24.3. In the 28th

SRPC meeting, CMD, APTRANSCO & APGENCO had stated that the issue

could be taken up with MoP for relaxation of the criteria for the compliance of

observations of Protection Audit.

24.4. Subsequently Chairperson, SRPC had taken again up this matter with Secretary (Power)

vide letter dated 19th

December 2015.

25. AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM

25.1. KSEBL vide letter dated 25th

September 2015 had stated that since all Southern states

would get benefitted with the early commissioning of Talcher-II transmission system, all

SR Constituents may jointly implead as a party in the Civil Appeal filed by TNEB

before Hon’ble Supreme Court. In the 27th

TCC meeting it was suggested that SR

constituents may jointly implead as a party in the Civil Appeal filed by TNEB in

Honorable Supreme Court.

25.2. Hon’ble Commission in its Order dated 05.11.2015 in respect of Petition No.

14/SM/2015, in the matter of ‘Notice under Section 19 of the Electricity Act, 2003 for

revocation of the inter-State transmission licence granted to Talcher II Transmission

Company Ltd.’ had passed the Order :

‘13. In exercise of our power conferred under Section 19 (3) of the Act and Regulation 20 of

the Transmission Licence Regulations notice is given to the licensee to show cause within

three months from the date of this order as to why the transmission licence granted for the

transmission project should not be revoked in terms of the provisions of Section 19 of the

Electricity Act and Transmission Service Regulation as quoted above. If no response is

received within three months from the date of issue of the order, the licence shall be deemed

to have been revoked.’


26. APPROACH BEING TAKEN BY CTU FOR RESERVING THE

TRANSMISSION CAPACITY FOR THE CUSTOMERS WHO HAVE AVAILED

LTA WITHOUT IDENTIFYING BENEFICIARIES

26.1. KSEBL vide letter dated 25th

September 2015 had suggested that CTU be requested to

take an approach that though LTA could be applied based on target region, availing or

booking of corridor for such LTA applicants could be made only after signing PPA with

firm beneficiaries. Further, LTA applicants earlier applied based on target region may be

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

customer approaches CTU with firm PPA and when there are transmission corridor

constraints.

26.2. The following was noted in the SRPC Meeting:

KSEBL had pointed out that the generators had been granted LTA with target region

about 5-6 years ago. The prospect of entering PPAs by these generators was quite

remote. Most of the generators were selling power under STOA/MTOA. Many

generators were not paying transmission charges since LTA had not been

operationalized. Basic issue was the time limit for the LTA to get operationalized

and also applicability of the transmission charges. KSEB felt that this arrangement

was blocking eligibility of other states.

CTU had stated that most of the referred generators had been granted LTA in 2009-

10. Transmission corridors were planned for them which was getting commissioned

in phases. LTA would get operationalized once the identified system is commissioned

and they would be liable to pay transmission charges. System takes around 3 -4 years

to develop. It was also pointed out that the Regulation allowed application with only

target region.

26.3. KSEBL issue was heard on Petition No. 249/MP/2015 on the following subject :

Petition under Section 79(1) (c) and 79(1)(f) of the Electricity Act, 2003 and Regulation

32 of the Central Electricity Regulatory Commission (Grant of Connectivity, Long-Term

Access and Medium-Term open access in Inter-State transmission and related matters)

Regulations, 2009, seeking intervention of Hon'ble Commission 'in the matter of non-

grant of LTA from the start date sought for in the LTA applications made in December

2014 with firm PPAs executed under DBFOO bidding framework between Generators

and KSEB Ltd., despite availability of ATC during the time frame sought for in the LTA

application, by reserving ATC in favour of very old target region LTA customers who

failed to submit firm PPAs to the intended regions within a reasonable period, causing

irreparable financial loss to KSEB Ltd. and other related matters.


27. PENDING REACTIVE CHARGES

27.1. PED vide letter dated 28.12.2015 had informed that payment of Rs. 6,12,755 was

pending from APTRANSCO towards reactive energy charges for the period 04.02.2013

to 30.08.2015. The issue was discussed in the 30th

CCM meeting wherein APTRANSCO

informed that LoA has been raised and dues would be cleared in a few days.

27.2. TSPCC vide letter dated 18.12.2015 had informed that payment of Rs. 1,23,25,064 ( for

the period 23.02.2015- 29.11.2015) & Rs. 1,42,99,492 (for the period 09.06.2014-

11.01.2015 ) was pending from APTRANSCO towards reactive energy charges and

interest. The issue was discussed in the 30th

CCM meeting wherein APTRANSCO

informed that an amount of Rs. 138 Crores was due from TSTRANSCO towards

transmission and wheeling charges. It was agreed that a reconciliation meeting would be

held between AP & TS.

28. TRANSMISSION CHARGES LIABILITY FOR THE LONG OUTAGE/

SUSTAINED INABILITY TO MAINTAIN THE APPROVED INJECTION

28.1. TANTRANCO vide letter dated 30.12.2015 had expressed concern over long outage of

generators and also inability of some generators to sustain approved injection. As per

POC regulations, TN has paid withdrawal charges for withdrawal quantum. TN had

requested that the whenever a Generating unit is under long shutdown or not maintaining

the approved injection quantum for long time, then transmission charges for that period

be paid by Generators alone and it should not be passed on to the DIC/Beneficiaries

bills.

28.2. The issue was deliberated in the 30th

CCM, wherein it was noted that in absence of

specific Regulation, TANTRANSCO/ other constituents may consider approaching

Hon’ble CERC through a Petition.

29. REIMBURSEMENT OF SRPC EXPENDITURE

29.1. Statement showing net amount payable by Member Utilities of SRPC for the year 2015 -

16, after adjustment of surplus/deficit for the previous period is furnished in Annexure-

XXXVII.

29.2. Fund Requirement for NPC:

In the 4th

NPC meeting held on 10.12.2015 (MOM dated 1.1.2016), it was agreed

that for the time being, expenditure towards hosting the various meetings of NPC

meetings be met by RPCs on rotational basis.


30. GRID OPERATION

Tamil Nadu had placed on record appreciation for the efforts of PGCIL for the

active support extended during the recent crisis due to heavy rains/floods.

Active support extended by SRLDC constituents, Generators and PGCIL in the

Crisis management in TN necessitated by heavy rain/flooding.

Black Start Workshop for Telangana System was conducted on 20th

November

2015 at Vidyut Soudha, Telangana by SRLDC

MVAR testing at Sharavathi HEP and Black Start workshop in Karnataka System

had been conducted successfully on 27.10.2015 and 03.11.2015 respectively and

the efforts made by KPTCL/KPCL/SRLDC officers in this regard were placed on

record

Black Start Workshop for Karnataka system was conducted on 3rd

November 2015

at Bangalore.

Unit - 7 of Ramagundam Thermal Power Station completed 458 days of continuous

operation . This unit had overtaken the record of Simhadri Stage I Unit I which had

made uninterrupted operation for 441 days. Earlier Unit-6 of Ramagundam had

been completed 406 days of continuous operation which was interrupted during

Grid disturbance

30.1. Grid events/highlights during October 2015

Frequency profile was better compared to last year and last month. Frequency

histogram shows same pattern as last year and last month.

As per load duration curve of October 2015, the loads had considerably increased

when compared to previous month & year.

Reservoir position as on 31.10.2015 was lesser than 41 % of last year same date.

Hydro Storage was less by around 4950 MU compared to last year.

Hydro generation was 2000 MU less in the month of October 2015 when compared to

October 2014.

Some wind generation was observed in first week of October 2015 and after that

completely stopped.

220 kV Appayyadorapalem (ADR Palem) in Viziznagaram district was

commissioned on 15.10.2015 by APTRANSCO

220/132 kV Miyapur S/s of 1x160 MVA Transformer Capacity was augmented to

2x160 MVA Transformer Capacity on 07.09.2015 by TSTRANSCO.

220 KV D/C XLPE UG Cable from 220 kV Moulali SS to 220 KV GIS at Osmania

University in Hyderabad of cKm 17.926 was commissioned on 14.10.2015 by

TSTRANSCO.

220 KV line on Narrow Based Multi Circuit Towers with 4 Circuits for LILO of both

Circuits of Dindi - Chandrayangutta 220 KV D/C Line to the proposed 220 kV SS,

Bonguloor of ckm 2 was Commissioned on 31.10.2015 by TSTRANSCO.

LILO of 220kV Ramagundam- Mandamarry circuit-I to 220/6.6kV LI SS Murmur in

Karimnagar district of 3.9 ckm was commissioned on 21.10.2015 by TSTRANSCO.

220 KV 2nd

ckt stringing from 220 KV RSS 220 KV Mandamarry (34 KM) in

Karimnagar of 34 ckm was commissioned by 20.10.2015 by TSTRANSCO.

LILO of 220kV Ogulapur- Durshed to 220/6.6kV LI SS Bommakal in Karimnagar

district of 0.108 ckm was commissioned on 27.10.2015 by TSTRANSCO.

220/132 KV GIS Osmania University in Chilakalaguda, Hyderabad was

commissioned on 14.10.2015 by TSTRANSCO.


220/6.6KV Murmur LI substation in Karimnagar district was commissioned on

21.10.2015 by TSTRANSCO.

220/6.6KV Bommakal LI substation in Karimnagar district was commissioned on


220/6.6KV Mallaram LI substation in Medak district was commissioned on


220/132 KVSS Bonguluru in Ranga Reddy Dist. (originally charged with

1x100MVA) was commissioned on 31.10.2015 by TSTRANSCO.

MoP had allocated 200 MW of Power Round the Clock(RTC) to Karnataka from

Unallocated Power of ISG Stations of SR by reducing the share from the shares of

Andhra Pradesh and Telangana by 50 MW, Kerala by 20 MW and Tamil Nadu by

80 MW w.e.f 06.11.2015.

Peak Demand of AP touched all time maximum of 6913 MW on 29th

October 2015.

Peak Demand of TS touched all time maximum of 6849 MW on 16th

October 2015.

PGCIL vide letter dated 16.10.2015 had informed that consequent to the successful

completion of Trial Operation, Transmission system associated with Kaiga 3 & 4

(2x235 MW) Project (Mysore-Kozhikode 400 D/C line along with new 400/220 kV

S/S with 2x315 MVA ICTs and 2x50 MVAR switchable line reactors at Kozhikode

and associated bay equipment at Mysore Substation) had been put under COD w.e.f

00:00 hours of 16th

October 2015 in terms of Clause 4 of CERC(Terms and

Conditions of Tariff) Regulations 2014.

30.2. Grid events/highlights during November 2015

As per load duration curve of November 2015, the loads had considerably reduced

when compared to previous month.

Reservoir position as on 30.11.2015 was lesser by 34 % w.r.t. last year. Hydro

Storage was less by around 3790 MU compared to last year.

Hydro generation was 1536 MU less in the month of November 2015 when compared

to November 2014.

Wind generation was observed very less during November 2015.

7.5 WM Installed Capacity was added in Tamil Nadu in Private Sector during the

month of November 2015.

Unit – VI at Nagjhari Power House up rated from 135MW to 150MW.

220kV D/C Line from Pallantla substation to 220/11kV LIS substation at Pattiseema

in East Godavari district of 60 CkM was commissioned (feeder I on 06.11.2015 &

feeder II on 07.11.2015) by APTRANSCO.

220kV Appayyadorapalem - Bobbili SC line in Vizianagaram District of 84 CkM was

commissioned on 12.11.2015 by APTRANSCO.

220/11 kV LIS substation at Pattiseema in East Godavari district of 60 MVA

Capacity was commissioned on 08.11.2015 by APTRANSCO.

Bobbili Growth Center 220kV SS in Vizianagaram District of 100 MVA Capacity

was commissioned on 13.11.2015 by APTRANSCO.

2nd PTR at 220kV SS Rachagunneri in Chittoor district of 100 MVA Capacity (2

nd

PTR) was commissioned on 25.112015 by APTRANSCO.

220kV SS Kalyandurg in Ananthapur District(220 kV, 2x100 MVA) was

Augumented to a capacity of 3x100 MVA and commissioned on 02.11.2015 by

APTRANSCO.

220kV SS Kamavarapukota in East Godavari District (220 kV, 2x100 MVA) was

Augumented to 3x100 MVA capacity of and was commissioned on 21.11.2015 by

APTRANSCO.


220 kV D/C Line from Pallantla substation to 220/11kV LIS substation at

Pattiseema in East Godavari district of 60 CkM was commissioned. (feeder I

on 06.11.2015 & feeder II on 07.11.2015) by APTRANSCO.

220 kV LILO to 220 kV existing Gajwel-Kamareddy line to 220/6.6 kV water

pumping SS to Kondapaka of 19.5 CkM was commissioned on 10.11.2015 by

TSTRANSCO.

220/6./6 kV Kondapaka water pumping substation in Medak District of 63 MVA

Capacity was commissioned on 10.112015 by TSTRANSCO.

220/132/33 kV SS Waddekothapally in Warangal District (3x100 MVA) capacity

was Augumented to a Capacity of (1x160 +2x100) MVA and was commissioned on


220/132/33 kV Boothpur SS in Mahaboobnagar District (2x100+1x160+1x16) was

Augumented to a capacity (2x100+1x160+1x16+1x50) and was commissioned on


220/132/33 kV SS Narketpally in Nalgonda District of (1x31.5+1x15) MVA capacity

was Augumented to a capacity of (1x50+2x31.5) MVA and was commissioned on


220/132/33 kV SS Kalwakurthy in Mahaboobnagar Dist.of (1x50+2x31.5)MVA

Capacity was Augumented to a Capacity of 2x50+1x31.5 MVA and was

Commissioned on 16.112015 by TSTRANSCO.

765kV Kudgi – Kolhapur I charged at 400kV level on 14th

November 2015 by

PGCIL

400kV Narendra – Kudigi I charged on 17th

November 2015 by PGCIL

400kV Gooty – Madhugiri (Tumkur) D/C charged on 29th


400kV Kudgi –Kudgi NTPC charged on 17th


400/220kV ICT- 3 & 63 MVAR Bus Reactor at Raichur was charged for first time on

24th

November 2015 by KPTCL.

63 MVAR Bus Reactor charged at 400kV Talaguppa S/S on 26th

November 2015 by

KPTCL..

125 MVAR Bus Reactor charged at NCC for first time on 04th

December 2015


completion of Trial Operation, the following assets under Transmission System

Associated with “Contingency Plan for evacuation of Power from IL & FS (2x600)

MW have been put under Commercial Operation with effect from 00:00 hrs of

November, 2015 in terms of Clause 4 CERC (Terms and conditions of Tariff)

Regulations, 2014.

Strengthening of Neyveli TS II – TS- I expansion Link with higher Capacity

Conductor).

PGCIL vide letter dated 01.12.2015had informed that consequent to Successful

completion of Trial Operation, the following assets under “Transmission System

associated with System Strengthening –XIII in Southern Regional Grid” have been

put under Commercial Operation w.e.f 00:00 Hrs of 1st December 2015 in terms of

clause 4 of CERC (Terms & Conditions of Tariff) Regulations 2014 and 27th SRPC

minutes of meeting point No 3.2.3.

Gooty – Madhugiri 400KV D/C line

Extension of 400/220KV substation at Gooty – Madhugiri 400KV D/C Line.

400/200KV Substation at Madhugiri (Tumkur) with 2x500MVA

Transformers and 1x63MVAR Bus Reactor along with associated bay &

Equipments for Gooty – Madhugiri 400KV D/C Line.

Transmission charges of the above assets are payable with effect from 1st

December 2015.


PGCIL SR II vide letter dated 11.12.2015 had informed that consequent to the

successful completion of Trial Operation the following assets under Transmission

System associated with “System Sregthening-XVII in Southern Grid” have been put

under Commercial Operation with effect from 00:00 hrs of 11th

December 2015 in

terms of Clause 4 of CERC(Terms and Conditions of Tariff) Regulations, 2014.

Second Circuit of Narendra(New Kudgi) – Kolhapur(New) 765 D/C

Transmission line(initially charged at 400 KV) along with bays & equipments

at Narendra(New Kudgi) substation and Kolhapur(New) substation.

Transmission charges for the above assets are payable with effect from 11th

December 2015.


successful completion of Trial Operation the following assets under “Sub Station

Extension works associated with transmission system required for evacuation of

power from Kudgi TPS(3x800 MW in Phase I) of NTPC Limited in Southern

Regional Grid” have been put under Commercial Operation with effect from 00:00

hrs of 11th

December 2015 in terms of Clause 4 of CERC(Terms and Conditions of

Tariff) Regulations, 2014.

4 Nos. 400 kV Line bays at Narendra(New, Kudgi) for Kudgi TPS-Narendra

(New, Kudgi) 400 kV 2xD/C Quad Lines.


December 2015.



System associated with “System Sregthening-XVII in Southern Grid” have been put

under Commercial Operation with effect from 00:00 hrs of 11th

December 2015 in

terms of Clause 4 of CERC(Terms and Conditions of Tariff) Regulations, 2014.

Narendra(New Kudgi) – Narendra(Existing) 400 kV D/C Quad Transmission

line along with associated bays & equipment at Narendra(New Kudgi)

substation and Narendra(Existing) substation.


December 2015.



System associated with “System Strengthening-XXII in Southern Grid” have been

put under Commercial Operation with effect from 00:00 hrs of 15th

December 2015

in terms of Clause 4 of CERC(Terms and Conditions of Tariff) Regulations, 2014 and

27 SRPC Minutes of Meeting point No. 3.7.

Kurnool(New) – Raichur 765 kV S/C line.

Extension of 765/400 kV S/S at Kurnool(New)- 1 No. 765 kV line bay for

Kurnool(New) – Raichur 765 kV S/C line

Extension of 765/400 kV S/S at Raichur - 1 No. 765 kV line bay for

Kurnool(New) – Raichur 765 kV S/C line


December 2015.

Andhra Pradesh, Telangana, Kerala & Tamil Nadu imported 363 MU, 1236 MU, 10

MU & 74 MU respectively intra-regionally through bilateral exchanges.

Andhra Pradesh, Telangana, Karnataka, Kerala& Tamil Nadu imported 284 MU, 285

MU, 9 MU, 113 MU & 906 MU respectively inter-regionally through bilateral

exchanges.


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

imported 105 MU, 115 MU, 53 MU, 102 MU & 13 MU respectively through Power

Exchange.

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

TPCIL exported 9 MU, 40 MU, 125 MU, 2.51 MU, 10 MU, 28 & 25 MU

respectively through Power Exchange.

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

1026 MU, 11 MU, 573 MU & 74 MU intra-regionally.

CoD of LANCO St 3 Unit 3A was declared on 11.08.2015.

CoD of Unit-II (800 MW) of SDSPP (Krishnapatnam JV) of APGENCO was

declared on 00:00 hrs of 24.08.2015

Unit-I (600 MW) of IL &FS was synchronized to grid on 05.08.2015.

Unit-II (500 MW) of NTPL was declared CoD on 00:00 hrs of 29.08.2015.

0.75 MW Wind Generation Capacity was added in Tamil Nadu.

The following assets under “ Transmission System associated with System

Strengthening –XVIII in SR grid “ along with Communication Signal from sending

end to receiving end, metering, telemetry and protection system had been put under

CoD 08.08.2015:

400 kV Vijayawada (Nunna PG)- Nellore (APTRANSCO) Ckt-III along with

1 x 63 MVAR line reactor.

400 kV Vijayawada (VTPS)-Nellore (APTRANSCO) along with 1 x 63

MVAR line reactor.

30.3. Grid events/highlights during December 2015

As per load duration curve of December 2015, the loads had marginally increased

when compared to previous month. Around 60 % of time the loads remained more

compared to last year same month.

Reservoir position as on 31.12.2015 was lesser by 28 % w.r.t. last year. Hydro

Storage was less by around 2876 MU compared to last year.

Hydro generation was 1300 MU less in the month of December 2015 when compared

to December 2014.

Kakatiya TPP Unit-2 (600 MW) was first time synchronized on 15th December 2015

by TSGENCO.

Hinduja NPCL Unit-1 (520 MW) in AP was first time synchronized on 25th

December 2015.

Bellary TPS Unit -3 (700 MW) was first time synchronized on 25th December 2015

by KPCL.

Coastal Energen Unit -2 (600 MW) in TN was first time synchronized on 28th

December 2015. CEA vide letter dated 06.01.2016 had communicated that M/s

Coastal Energen Private Limited vide their letter dated 04.01.2016 had informed that

Mutiara TPP Unit II(600 MW) had been achieved Full Load on 02.01.2016

765 kV Raichur – Kurnool Line I was charged on 13th December 2015 by PGCIL.

400 kV Nagarjunasagar – Khammam II & III were charged on 31st December 2015

by PGCIL


completion of Trial Operation, the following assets under “Substation works

associated with System Strengthening in Southern Region for import of Power from

Eastern Region” have been put under Commercial Operation with effect from 00:00

hrs of 4th January 2016 in terms of Clause 4 CERC (Terms and conditions of Tariff)

Regulations, 2014.


400 kV Bays each at Khammam(Existing) and Nagarjunasagar for

terminating Khammam - Nagarjun Sagar 400 kV D/C line has been

implemented under Tariff Based Competitive Bidding.

Transmission charges of the above assets are payable with effect from 4th

January 2016.

PGCIL vide letter dated 03.01.2016 had informed that on successful completion of

seventy two (72) hours of connection with the interconnection facilities the following

element is put under Commercial operation w.e.f. 1600 Hrs on 03.01.2016 in terms of

article 6.2.1, Transmission service Agreement (TSA) dated 14.05.2013 and

accordingly POWERGRID Vizag Transmission Limited is entitled for all benefits

envisaged in the aforesaid TSA.

400 kV Khammam(existing) – Nagarjunasagar Transmission D/C line under

Transmission system for System Strengthening in Southern Region for import

of power from Eastern Region.

In the 116th OCC Meeting KPCL had informed that Yeramarus Unit I had been

synchronized for the first time on 09th

February 2016.

30.4. Installation of Shunt Capacitors

Progress of installation of capacitors by the constituents during the year

2015-16 is furnished in the Table below:

(Figures in MVAR)

State Requirement

for 2015-16

Installed during the year 2015-

16 (till 31.01.2016)

Andhra Pradesh 26.20 0

Karnataka 56.31 0

Kerala 10.00 0

Tamil Nadu 122.40 2.4

30.5. DEMAND VARIATION (Peak Vs Off-peak)

Issue regarding large variation between minimum and maximum demands has been

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

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

October 2015 to January 2016:

Description

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala Tamil Nadu Puducherry

Southern

Region

October 2015

Highest 6913 6849 7460 3479 13307 332 35808

Date (Day) 29.10.2015

(Thursday)

16.10.2015

(Friday)

26.10.2015

(Monday)

26.10.2015

(Monday)

16.10.2015

(Friday)

17.10.2015

(Saturday)

29.10.2015

(Thursday)

Lowest 4312 4625 4232 1733 8128 190 24487

Date (Day) 11.10.2015

(Sunday)

22.10.2015

(Thursday)

05.10.2015

(Monday)

05.10.2015

(Monday)

05.10.2015

(Monday)

31.10.2015

(Saturday)

05.10.2015

(Monday)

Average 16.36 17.49 17.02 38.64 21.66 30.32 14.25

November 2015

Highest 6755 6479 7623 3426 12481 319 35383

Date (Day) 06.11.2015 05.11.2015 19.11.2015 27.11.2015 03.11.2015( 03.11.2015 04.11.2015


(Friday) (Thursday) (Thursday) (Friday) Tuesday) (Tuesday) (Wednesday

)

Lowest 3256 4514 5107 1835 4723 27 21980

Date (Day) 17.11.2015

(Tuesday

20.11.2015

(Friday)

22.11.2015

(Sunday)

15.11.2015

(Sunday)

10.11.2015(

Tuesday)

09.11.2015

(Monday)

10.11.2015

(Tuesday)

Average 22.15 16.40 22.71 38.59 29.98 39.74 21.03

December 2015

Highest 6540 6138 8396 3471 12680 309 35758

Date (Day) 31.12.2015

(Thursday)

24.12.2015

(Thursday)

30.12.2015

(Wednesda

y)

16.12.2015

(Wednesday)

31.12.2015(

Thursday)

24.12.2015

(Thursday)

31.12.2015

(Thursday)

Lowest 4031 3657 5415 1841 6141 128 23362

Date (Day) 07.12.2015

(Monday)

24.12.2015

(Thursday)

01.12.2015

(Tuesday)

26.12.2015

(Saturday)

04.12.2015(

Friday)

03.12.2015

(Thursday)

03.12.2015

(Thursday)

Average 23.12 21.41 19.33 37.99 29.17 37.24 20.81

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

30.6. FREQUENCY OF OPERATION OF SOUTHERN GRID

Frequency of operation of the Southern Grid for the period under review is

furnished below please:

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

October 2015 0.00 0.04 15.28 44.66 23.67 16.16 0.19 68.33 49.98

November 2015 0.00 0.04 12.53 41.44 24.78 21.00 0.20 66.22 49.99

December 2015 0.00 0.08 17.33 42.94 21.93 17.42 0.29 64.87 49.98

January 2016 0.00 0.00 11.45 42.75 25.88 19.60 0.32 68.63 50.00

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

XXXVIII) 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.

30.7. Reasons for demand -supply gap and its variation:

In 4th

NPC meeting held on 10.12.2015 (MoM dated 1.1.2016) the following was noted:

Reason for demand-supply gap needed to be clearly mentioned to reflect true

picture of power supply position in different states and also to invite attention

of various agencies including policy makers to the specific problem areas in

the power sector for suitable solution. It was requested to RPCs to advise the

states in their respective regions to intimate broad break-up of demand-supply

gap due to various reasons, or at least, the main reason(s) for demand-supply

gap in each month. It was suggested that this matter could be discussed in the


OCC forum of RPCs on regular basis and the reasons for demand-supply gap

ascertained from the States therein and communicated to CEA.

RPCs agreed to take action accordingly and furnish above information to

CEA along with the power supply position related data every month.

For Information of SRPC/TCC

31. PROTECTION SYSTEM ANALYSIS GROUP (PSAG-14) MEETING HELD AT

MAPS, KALPAKKAM ON 18.12.2015

31.1 In pursuance with the decision taken in the 49th

meeting PCSC, a meeting of Protection

System Analysis Group comprising officials from SRPC, SRLDC, PGCIL,

TANTRANSCO & MAPS was held on 16th

December, 2015 at MAPS, Kalpakkam to

discuss protection & operational issues concerning MAPS, in the context of Grid

Disturbance that occurred at S.P. Koil SS of TANTRANSCO & MAPS of NPCIL on 9th

November, 2015.

31.2 In the Meeting, apart from analyzing the events that led to the Grid Disturbance at S.P.

Koil & MAPS on 09.11.2015, the general operational & protection issues pertaining to

MAPS were also discussed. Specific recommendations have been given with regard to

the following issues:

Replacement of Disc Insulators on the 230kV lines emanating from MAPS.

Improving the flow/ exchange of information between MAPS and TANTRANSCO

substations for the faults occurring on the connecting lines.

Providing dual AC supply to Compressor Motor and redundant Compressor Unit.

Carrier communication/ PLCC related issues on 230kV MAPS-Arani line.

Status of providing Line CVT in the Y phase of all feeders excepting SP Koil-2.

Provision of Auto-reclosure on all 230kV lines emanating from MAPS.

Ensuring Grid Connectivity of MAPS

31.3 TANTRANSCO and MAPS have been requested to comply with the above set of

recommendations to prevent recurrence of Grid Disturbance such as that occurred on

09.11.2015.

32. THOROUGH REVIEW OF ALL THE DRAWAL POINTS OF STATES FOR

DRAWAL COMPUTATIONS

SRPC vide letter dated 30.10.2015 (Annexure-XXXIX) had suggested a methodology

for reviewing the Touch Points for drawl computations. The issue was discussed in the

30th CCM wherein the methodology was agreed in principle. It was agreed that SRLDC,

SRPC and respective states would review the drawl points.

33. INCLUSION OF DRAWAL OF MAHE IN REA

33.1 PED vide letter dated 11.01.2016 (Annexure-XL) had informed that including the drawl


of Mahe region into REA was approved in 21st SRPC Meeting. Metering equipment at

Panoor (KSEB) and Mahe would be commissioned by January 2016 end.

Communication facilities had also been established. It had been requested to arrange for

ABT compliant SEMs at both the ends. The issue was deliberated in 30th

CCM wherein

it was agreed that in line with CEA Metering Regulations KSEBL & PED would provide

ABT compliant SEMs respectively at their ends.

34. SHARING OF TRANSMISSION CHARGES OF TRANSMISSION ASSETS OF

NATIONAL IMPORTANCE

34.1 Hon’ble Commission in its Order in Petition No. 67/TT/2015 [ in the matter of approval

of transmission tariff ( PGCIL) of (i) Asset-I (HVDC Portion) and ( ii) Combined

Asset-II (AC portion) from anticipated COD to 31.03.2019 under the transmission

system associated with “North East-Northern / Western Interconnector-I Project” in

North Eastern, Northern & Western Region ] has decided to grant tariff of the assets

covered in the petition in terms of proviso (i) of regulation 7(7) of the 2014 tariff

regulations. SRPC vide letter dated 13.01.2016 (Annexure-XLI) had brought to

attention of SR entities, the highlights of the Order.

Hon’ble Commission in the Order (Sharing of Transmission charges) had stated

the following in item Para 30:

“Since, these assets are proposed to be considered as assets of national importance

and all the regions are proposed to bear the transmission charges, we consider it

necessary to hear the DICs of all the regions”.


34.2 The issue was deliberated in the 30th

CCM and it was noted that SR entities could furnish

their comments to Hon’ble CERC.

35. ACCOUNTING METHODOLOGY FOR LKPL STAGE II AND LKPL STAGE

III

35.1 In case of LKPL Stg II and LKPL Stg III as both the units are connected to the same

outgoing feeders the bifurcation of LKPL Stg II and LKPL Stg III cannot be as carried

out using main meters since both lines are connected to same bus. For accounting of

LKPL Stg II and LKPL Stg III bus coupler was opened and accounting was carried out

using Main Meters. Keeping in view reliability of generation from Stage II & III, iIt is

proposed to close the bus coupler and use standby meters to apportion the generation

between LKPL Stg II and LKPL Stg III. The Energy accounting and audit meter (ABT

meter) in the Generating stations (LKPL Stg II and LKPL stg III) could be used as a

backup meter for standby meters.

35.2 The issue was deliberated in the 30th

CCM meeting and it was agreed to close the bus

coupler for reliability purpose. It was noted that accounting methodology would not be

changed during failure/spurious readings of Main and Standby SEMs and all the

commercial implications, if any, would be borne by LKPPL. It was in the interest of

LKPPL to provide backup SEMs for standby meters which would ensure correct

accounting during failure/spurious readings of Main/Standby SEMs

36. TPCIL REQUEST TO EXEMPT DEVIATION CHARGES

36.1 TPCIL vide letter dated 07.01.2016 (Annexure-XLII) had requested for to consider the

event of 30.12.215 as “force majeure” during CTU system outage (ISTS) and revise the

deviation account for the week 28-Dec-15 to 03-Jan-16.

36.2 The issue was deliberated in the 30th CCM wherein it was noted a Working Group of

NPC was meeting shortly to recommend the methodology for ‘Treatment of Bilateral

short term and collective transaction in case of grid disturbances’. The methodology

would be put up to NPC and finalized methodology would be communicated up to

Hon’ble Commission for further directions.

37. PROLONGED OUTAGE OF 765 KV RAICHUR-SHOLAPUR – 2ND

CKT

765 kV Raichur – Sholapur Circuit II owned by RSTCPL had tripped at 10:46 hrs on

02.01.2016 and was revived only at 13:03 hrs on 07.01.2015. The line was revived after

rigorous follow up by SRLDC/SRPC. Outage of this critical inter regional link affects

the security of the grid significantly and lead to huge reduction of TTC/ATC (around

2500 MW) resulting in curtailment of approved transactions. A Special Meeting was


held on 11.01.2016 with RSTCPL (minutes available in SRPC website) to deliberate in

detail about the delayed restoration of this line and number of actionable points were

finalized.

38. AP & TELANGANA SCHEDULING ISSUES OF SHARED PROJECTS &

OPERATIONAL ISSUES

A meeting on Scheduling issues of shared projects of AP & Telangana & Operational

issues was held at Hyderabad on 18th December 2015 (Minutes available on SRPC

website). Scheduling issues during backing down/reserve shutdown for load generation

balancing and integration of renewable was discussed. Since this issue had technical,

operational, commercial and regulatory implications it was recommended to flag for

discussion in higher forum to arrive at a long term solution. These issues had been

referred to CEA vide letter dated 4th

January 2016 (Annexure-XLIII) emphasizing that

the issue was required to be deliberated in threadbare.

39. POWER SUPPLY ISSUES AFFECTING METRO SERVICES

BMRCL services were affected on 21st December 2015 and on 17

th December 2015 due

to power supply issues which affected Metro operations. A Meeting to discuss

disruption of power supply affecting BMRCL services was held on 31st December 2015

(Minutes available in SRPC website). It needs to be ensured that the services of

BMRCL/Metros are not affected either due to grid side problem or due to electrical side

problems in the Metro network.

40. Outage Coordination through OCC

40.1 CERC Order dated 14.12.2015 on Petition No. 008/SM/2014 on Grid Disturbance

envisaged that only OCC approved transmission shut downs be availed. The Order states

that no unplanned outage can be approved and even construction activities need to be

planned.

40.2 The issue was deliberated in 115th OCC meeting held on 08.01.2016. After deliberations

it was agreed that in order to facilitate changes in the dates of construction outages,

critical shut downs etc. one more set of transmission proposals would be considered

through OCC Outage web group. Modifications in the dates of the constructions/critical

shut downs would only be considered (not normal AMP works) provided it is supported

by valid reasons.

40.3 The procedure to be followed is below:


Construction/critical shutdown proposals would be submitted to Outage Web

Group/SRPC/SRLDC in the requisite format by 20th

of the month for the outages

planned for next month.

SRPC/SRLDC would jointly review the proposal and furnish the details along

with observation/ATC curtailment etc. between 21st and 25

th of the month.

SRLDC would coordinate with NLDC /other RLDCs for the Inter – Regional /

critical elements shutdown proposals. It would be posted in the OCC Outage Web

Group.

Constituents/entities could revert back with observations between 26th

and 28th

of

the month in the OCC Outage Web Group. In case no comments received, shut

down would be treated as approved.

Approved outages would be posted on SRPC website before end of the month.

It needs to be noted that the new list of shutdown proposals would consists only

the modified/additional construction/critical shutdowns. Approval would be at the

discretion of SRLDC/SRPC/Constituents.

40.4 In the 4th

NPC meeting held on 10.12.2015 (MOM dated 1.1.2016), NLDC stated that

they were experiencing difficulty in coordinating planned shutdown of inter-regional lines

with the concerned RPCs since some RPCs were approving shutdowns early in the

month, while other RPCs were doing so somewhat later in the month. Keeping in view

the specific issue raised by NLDC, it was agreed that all RPCs would conduct OCC

meetings in a distributed manner by 15th of every month for finalizing the planned

shutdown of different transmission lines including inter-regional ones for the following

month, and 10 days’ time would be allowed to NLDC to finalize TTC/ATC etc. of

various inter-regional corridors taking approved shutdowns into consideration.

40.5 In the 116th

OCC Meeting SRLDC presented the details of outages availed vis-a -vis

outages approved in OCC. 49 % of outages were not availed as per the schedule in the

month of January 2016 which was a matter of concern. It was agreed that all the entities

would furnish the details of outages availed vis-a -vis outages approved along with

reasons

41. SCHEDULING OF NTPC RAMAGUNDAM SOLAR POWER PLANT (10 MW)

41.1 A Special Meeting was held on 17th November 2015 to discuss scheduling of NTPC

Ramagundam Solar Plant (10 MW) by SRLDC (Minutes available in SRPC website).

To facilitate scheduling by SRLDC, the following prerequisite criteria are to be met by

NTPC:

Forecasting of generation.

MW-MVAR data of the station.

Voltage at inter connecting point.

Inverter status

SEM as per CEA, Metering Regulations, 2006


Data compatibility with SRLDC format etc.

41.2 NTPC to kindly expedite the implementation.

42. Assessment of Metering Requirement

42.1 In the 25th

Meeting of Commercial Sub-Committee held on 22.08.2014, CTU had agreed

to furnish SEM requirement projections for next one year which would be installed by

CTU in line with provisions of CEA Regulations. STU and Generators were also

similarly requested to furnish the SEM requirement assessment for the next one year. In

the 28th Meeting of Commercial Sub-Committee held on 20th June 2015 CTU, STU and

generators had been requested to furnish the assessment of SEM requirement for the next

one year.

42.2 NTPC had furnished information regarding number of SEMs required by NTPC for next

one year. The requirement of SEMS for Kudgi STPP is as given below:

220 kV side – 15 Nos.

400 kV Side – 18 Nos.

42.3 APTRANSCO informed that 04 Nos. of SEMs were required by them for next one year.

It was observed that while the assessment of SEM requirement would facilitate the

utilities in timely procurement, it is the prime responsibility of the utilities to procure the

SEMs themselves.

42.4 CTU, STU and generators had been requested to furnish the assessment of SEM

requirement for the next one year.

43. IMPLEMENTATION OF PROTECTION SUITE / PROTECTION

MANAGEMENT SYSTEM FOR SOUTHERN REGION

43.1 In the 26th

SRPC meeting held on 20th December, 2014 at Visakhapatnam, SRPC had

approved the proposal to procure Protection Suite (Protection Management System) that

comprises Web based management software and protection setting calculation tool

through PSDF funding. The detailed scope of the work is enclosed at Annexure-XLIV.

In this regard, steps have been initiated to procure Protection Suite through PSDF

funding. The number of suites per utility required for Southern Region is listed below:

S.No Utility Quantity

1 Karnataka 6

2 Tamil Nadu 8

3 Andhra Pradesh 4

4 Telangana 4

5 Kerala 4

6 Puducherry 1


7 Power Grid 2

8 NPCIL 1

9 NTPC 1

10 NLC 1

11 SRLDC 1

12 SRPC 2

Total 35

43.2 After obtaining approval for PSDF funding, tendering process for executing Protection

Suite would be initiated. For evaluating the technical and financial bids that would be

received, a Committee comprising members from SR- Constituents would later be

constituted with approval of Chairperson, SRPC.

44. STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY

RESOURCES INTO THE GRID

Chairperson SRPC has approved the proposal for study programme on Integration of

Renewable Energy Resources (RES) into the Grid for SRPC constituents in line with the

proposal already approved for NRPC. Proposal has been submitted to the Appraisal

Committee of PSDF.

The countries where the Programme is to be organized are Germany and Spain. The

Programme content is for the higher management and middle level Management. The

Programme will be implemented in 3-4 batches. The total participants in the study

Programme are around 75. Byelaws and other procedures will be carried out with the due

approval of Chairperson, SRPC.

45. FURNISHING THE WIND GENERATORS DATA FOR PLEXOS STUDY OF

GREENING THE GRID PROJECT

As part of Greening the Grid Project, studies for integration of renewable in to the Grid

were being conducted in PLEXOS software. The network data for the PLEXOS study

case was imported from All India PSSE Base case which had been used in calculation of

ATC/TTC. The details of connectivity of renewable energy generators had not been

modeled in the base case since these generators were connected at voltage level below

132/110 kV. SRLDC vide letter dated 26.11.2015 (Annexure-XLV). had requested that

the information like Name of the generating station, Installed Capacity and details of the

nearest 132/110/220 kV stations where it was connected etc may be furnished in the

format given at the earliest preferably in EXCEL format

46. UPDATE ON 230 KV BHAVINI-KANCHIPURAM

TANTRANSCO vide letter dated 14.09.2015 (Annexure-XLVI) had informed

regarding commissioning of Kanchipuram S/S that tender had been floated and tender


opening date was on 11.09.2015. Substation works would be completed in one year from

the date of award of contract and 230 kV & 110 kV line works were already under

progress. It was also informed that meanwhile the feasibility of connecting 230 kV

BHAVINI-Kanchipuram line to the existing nearby substations was also under study.

However, since the commercial operation of BHAVINI unit was not yet decided and 4

nos. of 230 kV lines emanating from BHAVINI were already in service, there would not

be any constraint in power evacuation from the BHAVINI.

47. MEMBERSHIP OF NLDC

In the 4th

NPC meeting held on 10.12.2015 (MoM dated 1.1.2016), all RPCs informed

that the proposal of Membership of NLDC in the NPC was agreeable to them.

Accordingly, the Committee requested Member Secretary (NPC) to take up with MoP

the necessary amendment in the resolution of constitution of NPC.

48. MEMBERSHIP OF COASTAL ENERGEN

It is proposed to include Coastal Energen as a Member of SRPC since it meets the

criterion in the MoP resolution on RPC Membership.

49. ANY OTHER ISSUE WITH THE PERMISSION OF THE CHAIR

50. DATE & VENUE OF THE NEXT SRPC MEETING

southern regional power committee - karnataka · corridor due to laying of transmission line and...

Documents