SOUTHERN REGIONAL POWER COMMITTEE - Karnataka · third line which would evacuate power from...

Minutes of the 31st SRPC Meeting held on 25th February 2017

CONTENTS

1. INTRODUCTION............................................................................................................................................... 4

2. CONFIRMATION OF THE MINUTES OF THE 30th SRPC MEETING .................................................................... 7

3. MEMBERSHIP TO RPC ..................................................................................................................................... 7

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

AMENDMENT RULES, 2015............................................................................................................................. 8

5. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE ...................................................... 10

6. FLEXIBILITY IN UTILIZATION OF DOMESTIC COAL FOR REDUCING COST OF POWER GENERATION ............ 11

7 ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY ..................................................................... 12

8 CONGESTION RELATED ISSUES ..................................................................................................................... 14

9 COMPLIANCE OF ORDER OF HON’BLE CERC IN PETITION NO. 420/MP/2014 – IN RESPECT OF LVRT AND

OTHER PROVISIONS OF CEA/CERC REGULATIONS ....................................................................................... 17

10 INCLUSION OF DRAWAL OF MAHE IN REA ................................................................................................... 18

11 ISSUES IN RESPECT OF NPCIL/BHAVINI ......................................................................................................... 19

12 LOW VOLTAGES ............................................................................................................................................ 24

13 RELIABLE ALTERNATE AUXILIARY SUPPLY AT HVDC, BHADRAVATHI ........................................................... 24

14 DC FOR NTECL, VALLUR DURING VARDHA CYCLONE ................................................................................... 25

15 OUTAGE PLAN OF CENTRAL GENERATING STATIONS .................................................................................. 26

16 EXPERIENCES FROM VARDAH CYCLONE ....................................................................................................... 29

17 STATUS OF GENERATION IN ISGS ................................................................................................................. 31

18 REVIEW OF ULDC / SCADA/COMMUNICATION ............................................................................................ 33

19 URTDSM (PMU) PROJECT IN SOUTHERN REGION ........................................................................................ 36

20 SCHEDULING OF WIND & SOLAR GENERATING PROJECTS HAVING CAPACITY OF 500 MW AND ABOVE ... 39

21 ISSUES IN RESPECT OF CONNECTIVITY/LTA/LILO/INFIRM POWER ............................................................... 40

22 TTC/ATC ........................................................................................................................................................ 41

23 UPCOMING TRANSMISSION SYSTEM ........................................................................................................... 47

24 UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH TRANSMISSION NETWORK ........ 60

25 NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ................................................................ 65

26 NEW PROJECTS OF STATE SECTOR & IPP ...................................................................................................... 67

27 METHODOLOGY FOR CERTIFICATION OF INTRA-STATE TRANSMISSION LINE ............................................. 68

28 EMERGENCY RESTORATION SYSTEM (ERS) .................................................................................................. 69

29 PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR .............................................................. 71

30 OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS ....................................................... 77


31 NON-AVAILING OF OCC APPROVED SHUTDOWN ......................................................................................... 78

32 GRID STUDY COMMITTEE (TASK- 2) AUDIT PROGRESS DETAILS .................................................................. 79

33 STATUS OF PHASE I AND PHASE II OF PROTECTION AUDIT RECOMMENDATIONS ...................................... 80

34 SPARE ICT AND REACTOR PLACEMENT AND USAGE PROCEDURE ............................................................... 81

35 IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION .............................................................................. 81

36 SHARING OF TRANSMISSION CHARGES OF TRANSMISSION ASSETS OF NATIONAL IMPORTANCE ............. 94

37 THOROUGH REVIEW OF ALL THE DRAWAL POINTS OF STATES FOR DRAWAL COMPUTATIONS ................. 95

38 IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT SYSTEM (PMS) FOR SOUTHERN

REGION ......................................................................................................................................................... 96

39 POWER SYSTEM ANALYSIS GROUP (PSAG-17) MEETING HELD ON 3rd & 4th OCTOBER 2016 AT NTPC-

SIMHADRI STPS, KALPAKA SS AND HNPCL TPS ............................................................................................. 96

40 AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE TRANSMISSION LINES OF SOUTHERN

REGION ......................................................................................................................................................... 97

41 STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY RESOURCES INTO THE GRID ......... 98

42 SPECIAL MEETING WITH M/S KPCL HELD ON 27.10.2016 AT SRPC, BENGALURU ....................................... 98

43 IMPLEMENTATION OF LINE DIFFERENTIAL PROTECTION (LDP) ................................................................... 99

44 PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS ..................................................... 100

45 7th MEETING OF NATIONAL RELIABILITY COUNCIL FOR ELECTRICITY HELD ON 07.12.2016 AT NRPC, NEW

DELHI ........................................................................................................................................................... 100

46 SRPC REPORT ON “EFFECT OF DELAYED CLEARANCE OF FAULT ON TRANSMISSION SYSTEM” ................. 100

47 PROTECTION AUDIT OF 400 KV ALUNDUR SS OF PGCIL (SR-II) AND 230 KV ALUNDUR S/S OF TANTRANSCO101

48 SPECIAL MEETING ON NEYVELI GRID DISTURBANCE .................................................................................. 101

49 PENDING IMPLEMENTATION OF RECOMMENDATIONS OF PROTECTION COORDINATION SUB-COMMITTEE

(PCSC) OF SRPC ........................................................................................................................................... 102

50 COMMERCIAL COMMITTEE ISSUES ............................................................................................................ 102

51 ISSUES IN BILLING OF GENERATING STATIONS OWNED BY NTPC (TARIFF PERIOD 2014-19) .................... 104

52 TPCIL REQUEST TO EXEMPT DEVIATION CHARGES .................................................................................... 104

53 SCHEDULING OF NTPC RAMAGUNDAM SOLAR POWER PLANT (10 MW) .................................................. 105

54 SCHEDULING OF UNITS BELOW TECHNICAL MINIMUM AND OTHER ISSUES ............................................ 105

55 MONITORING OF SCHEMES FUNDED FROM PSDF ..................................................................................... 106

56 SALE OF URS POWER BY NLC STAGE-II ....................................................................................................... 106

57 SCHEDULING OF KAMUTHI SOLAR PARK .................................................................................................... 106

58 SETTLEMENT FOR THE PERIOD PRIOR TO BIFURCATION OF AP AND TELANGANA ................................... 107

59 AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM ........................................................................ 107


60 GRID OPERATION ........................................................................................................................................ 108

61 RELIABLE COMMUNIACTION SCHEME UNDER CENTRAL SECTOR FOR SOUTHERN REGION ..................... 119

62 OPGW LINKS ON LINES CONSIDERING LILO IN FUTURE ............................................................................. 119

63 ALLOCATION OF 6 FIBRES FROM THE 18 FIBRES AVAILABLE AS SPARE ..................................................... 120

64 FINAL LIST OF OPGW LINKS UNDER FIBRE EXPANSION PROJECT OF SOUTHERN REGION ......................... 120

65 OPGW STRINGING ON KPTCL LINES............................................................................................................ 121

66 REIMBURSEMENT OF SRPC EXPENDITURE ................................................................................................. 121

67 APPOINTMENT OF CONSULTANTS ............................................................................................................. 121

68 DATE & VENUE OF THE NEXT SRPC MEETING ............................................................................................ 121

69 CONCLUSION .............................................................................................................................................. 121

Minutes of the 31st SRPC Meeting held on 25.02.2017

SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

MINUTES OF THE 31st SRPC MEETING HELD ON 25

th FEBRUARY 2017 AT

BENGALURU

1. INTRODUCTION

1.1 The 31st Meeting of Southern Regional Power Committee (SRPC) was held on 25

th

February 2017 at Bengaluru. The list of participants is given at Annexure-I.

1.2 KPTCL welcomed the Members, Directors and participants to the 31st Meeting of SRPC. A

video was presented on „Invest Karnataka‟; some of the highlights of which are given

below:

Sivasamudram (4.2 MW) was the first hydro station in Asia commissioned in 1902 for

enabling gold mining at Kolar. The power was extended to Kolar through then longest

transmission line of 147 kms.

Karnataka was the first state to set up professionally managed entity at state level

(KPCL) to plan, construct, operate and maintain power generation. Since 1976, KPCL

has installed capacity of around 6,500 MW of thermal, hydro, solar and wind energy.

56% of which is hydel energy. Around 9,500 MW is in the pipe line to be

commissioned in the future.

MNRE sanctioned National Training Centre for Solar Technology to KPCL in 2011.

Functions of transmission and distribution of erstwhile KEB were carved out in 1999.

Shortly afterwards, KERC was set up to regulate all aspects of electricity sector in a

transparent manner.

KPTCL was further unbundled in 2002 and four independent Discoms were formed,

which was later made into five Discoms.

PCKL was incorporated in 2007 to further augment power supply procurement.

KPTCL has reduced losses to one of the lowest in the country at 3.66 %.

KPTCL was first in the country to commission largest SCADA network to

professionally operate and control transmission network.

KPTCL switched to compact substations and was the first state in India to use covered

conductors.

KPTCL was awarded best „Transmission Utility‟ in the country by CBIP.

KPTCL / Escoms have been responsible for electrifying nearly 100 % of the habitats

in Karnataka. By 2020, all the households in Karnataka would be electrified.

Bescom was chosen to host the Pilot Project for Smart Grid. Distribution Automation

System (DAS) has been implemented in Bescom.

CESC earned first prize towards National Energy Conservation.


KREDL is responsible for generating clean, green and renewable energy through wind

and solar projects. Government of Karnataka has revised its Solar Policy for 2014-

2021. Idea was to empower farmers through „Surya Raitha‟ and solar pump schemes.

Encouraging roof top solar and easy buyback polices are examples of the progress.

State is developing the worlds‟ largest solar park of 2,000 MW by 2017.

Hon‟ble Prime Minister of India had conferred the award for „Excellence in

Renewable Sector‟ to Karnataka.

By 2020, 8 crore population would be supplied 24x7 power in Karnataka.

1.3 Shri Jawaid Akhtar, MD, KPTCL extended a hearty welcome to all the delegates to the

meeting. At the outset, he welcomed Dr M Saikumar, Chairman, TNEB & Chairperson,

SRPC for making it convenient to attend this meeting despite his busy schedule. He made

a special mention of Shri S R Bhat, MS, SRPC who has been ably handling the issues of

SRPC. He welcomed all the Chairpersons, Managing Directors, Directors and CEOs to the

meeting.

On grid side, he informed that Karnataka had witnessed record energy consumption and

demand on 23.02.2017. However on the previous day, Karnataka had touched demand of

10,242 MW and energy consumption of 221.49 MU which were maximum till date. Major

evacuation system which was being undertaken since last two years consisted of six lines.

Out of three lines at 400 kV, one line (Bellary PS-Kelagina Kanive, Chitradurga District),

had been commissioned in the month of February 2017. The line from Kelagina Kanive to

Vasanthanarasapura would be completed within 10 days. Works in difficult areas of

Tumkur was over and the left out works were to be completed in Chitradurga District. The

third line which would evacuate power from KPCL‟s Yeramarus units would be ready by

April 2017. Out of three 220 kV lines, Vasanthanarasapura - Anthranasahalli and other

line from Vasanthanarasapura - Madhugiri would be completed within 15-20 days since

only couple of issues remain to be settled. Madhugiri-Pavagada line was expected before

March 2017. KPTCL had been able to complete more than 12-13 major works pending

since past 5-10 years. Most of these works were in and around Bengaluru and they were

trying to strengthen internal transmission lines within Karnataka, specifically around

Bengaluru.

1.4 Shri S R Bhat, MS, SRPC extended a special welcome to Dr M Saikumar, Chairman, TNEB &

Chairperson, SRPC. He also welcomed other SRPC members to the Meeting. He thanked MD,

KPTCL and his team for the excellent arrangements made for conduct of the Meeting.


1.5 SRPC welcomed the following new Members to SRPC:

i. Shri R K Verma, Member (GO & D), CEA

ii. Shri H Nagesh, Director (T), KPTCL

iii. Dr K Ellangovan, CMD, KSEBL

iv. Ms M A Helen, Director (Distribution), TANGEDCO

v. Shri A K Gupta, Director (Commercial), NTPC

vi. Shri Siva Rama Krishnan M, CEO, NTECL

vii. Shri K V S Baba, CEO, POSOCO

viii. Shri N Ramesh, CEO, IL & FS

ix. Shri P Panduranga Rao, CEO, LKPPL

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

i. Shri Paul Antony, CMD, KSEBL

ii. Shri T K Barai, Member (GO & D), CEA

iii. Shri S Sumanth, Director (Transmission), KPTCL

iv. Shri M Pandi, Director (Distribution), TANGEDCO

v. Shri U P Pani, Director (Commercial), NTPC

vi. Shri Thomas Joseph, CEO, NTECL

vii. Shri S K Soonee, CEO, POSOCO

1.7 Dr M Saikumar, Chairperson, SRPC & Chairman, TNEB at the outset thanked MD, KPTCL

for the excellent arrangements. He added that it was noted that TCC had a good Meeting on

the previous day. There were a couple of issues which need to be deliberated such as

integration of renewable energy. As was well known Tamil Nadu has considerable amount of

renewable. The associated problems being faced in this regard should be studied. The lessons

from the same should be shared and implemented in other places. Intra-day as well as inter-day

variations of wind were very high. There were cases where wind was 3,000 MW in the

morning, dropping to about 600 MW in the afternoon while completely disappearing in the

evening. At times even thermal plants had been backed down anticipating availability of 3,000

MW of wind but compulsory load shedding had to be subsequently resorted in peak hours.

This was happening as a matter of routine and thus planning was rather difficult. Some

resources were required which could quickly back down or ramp up. Karnataka and Andhra

Pradesh were also moving ahead in large scale renewable integration and it was reported that

Solar Energy Corporation was going in a big way for development in the country. It was to be

seen how such large scale integration would take place and also transmission requirements

needs to be provided in a timely manner. TN had been seeking green corridor for transfer of

renewable energy to other states. Assuming that all investments in Andhra Pradesh, Karnataka

and Tamil Nadu come up, it was to be assessed whether there would be a corridor to export.

Earlier only one state was getting affected, but now with large scale renewable integration in

number of states, the issues were getting magnified. All Constituents were proud about the


coming up of KKNPP units. However, one issue required to be sorted pertained to schedule

planning of large nuclear units like Kudankulam. In absence of backing down, there were

issues since more than 50 % power was allocated to Tamil Nadu. Second unit of KKNPP was

yet to be stabilized. Since power contracts were based on projected availability of KKNPP

units, any tripping of units/prolonged outages put the planning process in disarray.

1.8 The Agenda was taken up for discussions.

2. CONFIRMATION OF THE MINUTES OF THE 30th

SRPC MEETING

2.1 Minutes of the 30th

Meeting of SRPC held on 27th

August 2016 at Chennai had been

circulated vide letter dated 19th

October 2016.

2.2 Minutes of the Meeting were confirmed.

3. MEMBERSHIP TO RPC

3.1 Special Invitee /Membership status to M/s PTC in RPCs

3.1.1 In the 5th

Meeting of NPC held on 08th

April 2016, after deliberations, it had been agreed

that the issue of membership for Traders would be deliberated in respective RPCs and

outcome thereof would be communicated to CEA for taking up the matter with MoP.

3.1.2 In its 30th

Meeting, SRPC had concluded that the proposal to include M/s PTC as SRPC

Member could be deferred. Presently, composition as stipulated in the MoP Resolution

could be continued.

3.1.3 In the 6th


December 2016 (MoM dated 12.01.2017 available

on CEA website) the following had been noted:

Chief Engineer (GM), informed that as per the proposed amendment taken up with

MoP by CEA, a representative of each of nodal agency appointed by Government of

India for cross border power transaction with the countries having electrical

interconnection with the region also included as members of respective RPCs

irrespective of the trading volume. In such case PTC could be retained as a member of

ERPC. All other RPCs trader membership would be as per the present practice being

followed.

Member (GO&D) stated that since the matter would be sorted out by the proposed

amendment taken up by GM Division with MoP, further deliberation on the issue by

NPC was not required.

Chairperson, NPC observed that presently ER & NER were the regions involved in

cross border transaction of power. MoP may take a call on the proposed amendment in

the Resolutions of RPC for including traders who are involved in cross border trading

as members of respective RPCs.

NPC decided to await the outcome of proposed amendment of resolution by MoP.

3.1.4 SRPC noted the above.


3.2 Membership of IPPs in RPCs

3.2.1 In the 5th


April 2016, the following had been noted:

WRPC had proposed to enhanced the limit of 1,000 MW to 2,000 MW for

membership of IPP in RPCs. NRPC had suggested that instead of allowing them RPC

membership IPPs might be included in subcommittee like TCC/OCC.

NPC had suggested that this issue be deliberated first in respective RPCs and after

evolving a common view, same would be referred to MoP for amendment in

Resolution.

3.2.2 In its 30th

Meeting, SRPC had concluded that the present eligibility of 1,000 MW as

stipulated in the MoP Resolution could be continued in respect of Southern Region.

3.2.3 In the 6th

Meeting of NPC held on 19.12.2016 (MoM dated 12.01.2017 available on CEA

website) the following had been noted:

Member (GO&D) pointed out that MoP has issued individual Resolutions for each

RPC. Resolution in respect of WRPC could be proposed for amendment regarding

membership of IPPs.

After deliberation it was decided that GM Division, CEA would take up with MoP for

amendment in Resolution of WRPC in respect of eligibility condition of IPPs

membership in WRPC.


3.3 Representation from Power System Wing in RPC Meetings

3.3.1 In the 6th


December 2016 (MoM dated 12.01.2017 available on

CEA website) it was noted that in order to have fruitful deliberation on transmission system

related issues/schemes in TCC/RPC Meetings, Grid Management Division, CEA had

proposed that RPCs may invite Chief Engineer (PSP&A-I) / Chief Engineer (PSP& A-II),

CEA depending upon the region being dealt with, in respective TCC/RPC Meetings as a

“Special Invitee” on regular basis. It had been agreed that this proposal would be deliberated

in respective RPCs and outcome thereof communicated to NPC Secretariat.

3.3.2 TCC deliberations

It was opined that transmission related issues were being deliberated threadbare in the

Meetings of Standing Committee on Power System Planning. Further, the number of

participants was also required to be contained.

After deliberations, TCC had recommended that Chief Engineer (PSP&A-II) may be called

as a “Special Invitee” on a case to case basis as per any requirement.


4. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER

ENVIRONMENT (PROTECTION) AMENDMENT RULES, 2015

4.1 Revised water consumption and emission norms for existing as well as new thermal units (to

be installed from 01.01.2017 onwards) as per Environment (Protection) Amendment Rules,


2015 were notified by Ministry of Environment, Forest & Climate Change (MOEF & CC)

(Gazette Notification dated 07.12.2015). MOEF guidelines had classified thermal generators

into three categories with different norms. The three classes were - prior to 31st December

2003, 1st Jan 2004 to 31

st December 2016 and beyond 1

st January 2017. Existing as well as

new plants were required to meet standards by the stipulated time lines. Preparedness and

action plan in order to comply with revised norms had been discussed in SRPC and the

Subcommittee Meetings.

4.2 CEA, New Delhi vide letter dated 22.12.2016 (Annexure-II) had intimated that a

Committee headed by Chairperson, CEA had been constituted by Ministry of Power; Govt. of

India for preparing a phasing plan for implementation of new environmental norms issued in

December 2015 by MOEF &CC with regard to SPM, SOx & NOx emissions. 1st & 2

nd

Meetings of this Committee were conducted on 21st October 2016 and 13

th December 2016

respectively, wherein the following decisions had been taken:-

Region-wise lists to be prepared by CEA identifying thermal units for ESP up gradation

& installation of FGD. Lists in respect of Southern Region had been prepared and

enclosed at Annexure-1 to Annexure-4 of CEA‟s letter.

Concerned RPC to prepare phasing plan for above identified units for ESP up gradation

and FGD installation in consultation with concerned Power Utilities, SLDC &

POSOCO. RPCs were requested to complete above exercise within 1 month time and

furnish the same for inclusion in Report of the Committee.

Installation of low NOx burners in all coal based thermal units was discussed by the

Committee. It was brought to the notice of Committee, that all new units installed after

2004 onwards had low NOx burners/system. However, older units may not have low

NOx burners/system. Committee had recommended taking up installation of low NOx

system in these coals based thermal units during next over-hauling period positively.

Technical feasible options available for reducing NOx emissions were mentioned in the

letter/MOM.

4.3 Accordingly, a Meeting was conducted on 12th

January 2017 at SRPC, Bengaluru to

deliberate on status and also firm up Phasing Plan. (Minutes of the Meeting are available on

SRPC website). In the Meeting, Phasing Plan for FGD installation etc was firmed up. Other

issues in respect of the revised norms were also deliberated.

4.4 CMD, TANGEDCO vide letter dated 18.02.2017 (Annexure-III) had sought time extension of

two years for all the four units of MTPS-I to comply with the new environmental norms for

the desired SPM levels.

4.5 TCC deliberations

MS, SRPC had appraised TCC of the issues with regard to FGD installation, ESP up

gradation and low NOx burners/system. Schedule of FGD installation had been


communicated to CEA and was to be completed in the time frame of 2019-21. Installation

of low NOx system in coal based thermal units was to be carried out during next over-

hauling period positively. As noted earlier, there was no compulsion on phasing out of

units, provided revised environment norms were met. For seeking extension, CEA had

sought phasing plan for FGD installation which would be put up further to MoP.

Concerned generators had been requested to kindly initiate necessary action in this regard.

TCC had noted the requirements for necessary compliance.

TCC had suggested that some funding either from PSDF or any other fund could be

arranged from GoI to meet stipulated revised environment norms. Chairperson, SRPC

could be kindly requested to take up the matter with GoI.

4.6 SRPC deliberations

4.7 Chairperson, SRPC stated that most likely none of the entities may be in a position to meet

time frame for compliance of new environment norms. The issue had been taken up for TN

units with GoI, but response had not been very encouraging. Cost of Rs.1 to 1.5 crore per MW

to take up the works was also quite exorbitant. He added that all entities could suitably take

the request for time extension with the concerned Authorities.

4.8 It was agreed that Chairperson, SRPC would take up the issue with GoI for funding to meet

stipulated revised environmental norms.

5. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE

5.1 In the 29th

Meeting of SRPC, it had been agreed that a Task Force at TCC level could flag

issues and come out with Terms of Reference and possibly get it examined through a

Consultant. TCC in its 29th

Meeting recommended the TOR for renewable integration as

finalized in the Special TCC Meeting held on 02nd

August 2016 for approval of SRPC.

5.2 In the 30th

Meeting, SRPC had agreed to form a Working Group of Members from each of the

states, SRLDC and SRPC Secretariat to take forward the TOR by engaging a Consultant.

Constituent states of SRPC had agreed to share the financial commitment equally. It was

agreed that details would be put up to SRPC in the next Meeting.

5.3 Working Group of Members from each of the states, SRLDC and SRPC Secretariat had met

on 17.11.2016 and the TOR finalized is at Annexure-IV. As can be kindly appreciated there

are a number of reports/studies undertaken or being taken up in this field. It was thus felt

prudent to fine tune the TOR in discussion with experts/staff of POSOCO etc., to avoid any

possible duplication in the proposed study.


NLDC had informed that some reports on the subject were already available (links

available at Annexure-V). Available study material could thus be used to the extent


possible to cut down on cost of proposed study.

SRPC had informed that as per preliminary assessment, the cost could be around Rs.3.50

crores. SRPC Secretariat was also trying to fine tune the TOR in consultation with

experts/staff of CERC & POSOCO.

TANTRANSCO had suggested that this study/report could be funded by RE developers,

especially since objective was to facilitate RE integration smoothly, safely and securely

into the grid.

TCC had requested TANTRANSCO/TANGEDCO to use their good offices and take up the

matter with RE Developer Associations. TANTRANSCO/TANGEDCO had agreed to take

up the matter with the RE Developer Associations for possible funding of the consultancy.

5.5 SRPC noted the above.

6. FLEXIBILITY IN UTILIZATION OF DOMESTIC COAL FOR REDUCING COST OF

POWER GENERATION

6.1 MoP vide letter dated 10.06.2016 had informed that on 4th

May 2016, Cabinet had approved

proposal of Ministry of Power for flexibility in utilization of domestic coal for reducing cost

of power generation. Presently, share of generation from coal based power plants was about

78 % of the total generation in the country. These coal based power plants are supplied coal

against plant specific Fuel Supply Agreement (FSA). There are some power plants which

generate cheaper power than others. There was scope for utilization of coal in such power

plants to achieve overall reduction in cost of generation.

6.2 In this regard, approved mechanism for allowing flexibility in utilization of domestic coal

amongst power generating stations to reduce the cost of power generation was deliberated in

the 29th

TCC/30th

SRPC Meetings. The following had been noted in the Meeting:

TANGEDCO had stated as per computations, in Case-1 (use of coal aggregated with the

state in its own State GS), the cost is reducing. Ib valley coal (2,000 kM) linked to Mettur

could be utilized in North Chennai St-II. Presently computations for Case-2 (use of coal

aggregated with one state in GS to other state‟s utilities) would be difficult to assess.

Case-3 (use of coal aggregated with state in CGS and vice versa) could also be utilized

by TANGEDCO as in some earlier cases NTECL & NTPL were requiring coal.

CEA had informed that certain apprehensions were envisaged during the formulation of

this methodology. The methodology could be utilized only if there are some financial

benefits. Sample computations were carried out in consultation with NTPC; and the

estimated benefit for NTPC for one year was around Rs 760-900 Crores on internal

optimization only. Sample computations for Koradi (MAHAGENCO) had also shown

substantial saving (around 39 paise/unit in variable cost). The three Ministries i.e Power,

Coal and Railways had come together for implementation of the scheme. There would be

no rebooking charges by the Railways during diversion of coal under this scheme. Case

2 & 3 could be utilized which would a learning experience and subsequently Case 4

could be initiated in a transparent manner.


NTPC had clarified that the scheme had been implemented for intra-state GENCO

stations and between NTPC and GENCO stations also. After experience, MoP may open

the scheme for IPPs. The whole essence of the scheme was to minimize the cost of

power. Within NTPC, coal could be transferred within various stations, maximizing

generation at pit head stations while non pit head stations could possibly be run on partial

loading, for maintaining spinning reserve and taken for reserve shut down as per system

requirement.

After deliberations, SRPC had suggested that states/generators may approach

CEA/CERC/SERC in line with the methodology with sample computations to utilize the

scheme for reducing cost of power.

6.3 Subsequently, CEA had informed that a web portal „Coal Mitra‟ had been created on 23rd

December 2016. Through this, traders could find suitable case / options for Coal transfer.

6.4 MoP vide letter dated 20.02.2017 (Annexure-VI) had released the Methodology for use of

Coal by State in Private Generating Stations (IPPS).


MS, SRPC had appraised TCC about „Coal Mitra‟ Portal (http://www.coal-mitra.com).

Certain details such as variable cost, fixed cost, linkage, nodal officers, calculator etc was

already available on the portal.

NTPC had informed that the scheme had been implemented among some NTPC stations

and informed that Moudha was a success story. Gujarat Government was also in touch with

NTPC for possible coal swapping. NTECL had informed that proposal was still under

discussion stage.

TANGEDCO had informed that they were utilizing the scheme among few of its state

generators.

TCC had requested the generators to examine the options to avail the benefits under the

scheme.


7 ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY

7.1 In the 29th

Meeting of SRPC it had been noted that in the matter of Roadmap to

operationalize Reserves in the country, Hon‟ble CERC vide Order dated 13.10.2015 on

Petition No. 11/SM/2015 had 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.

http://www.coal-mitra.com/


(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 utilizing of spinning reserves and

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

st

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.

7.2 In earlier Meetings the following had been noted:

NLDC had informed that AGC issues were being looked into by the Expert Committee of

Members. They had sought some more time from Hon‟ble CERC for operationalizing the

reserves since many other issues such as telemetry etc., were to be addressed. NTPC was

responding positively and the process of transmitting signals to the station as a pilot

project was being contemplated in each region. Changes in generators side controls were

required and NTPC was taking a lead in it.

SRLDC had informed that a Pilot Project had been taken up through M/s Siemens and

NTPC. Action was being taken for the detailed report of NLDC through Consultant and

in a couple of months, the report would be submitted. Feedback on Ancillary services had

been given to Hon‟ble CERC. ACE would soon be posted on website for the benefit of

all entities. POSOCO would also be conducting a workshop on AGC issues.

After deliberations, it was noted that NLDC/SRLDC would conduct workshops as part of

capacity building exercise and also display ACE on its website.

7.3 Subsequently, POSOCO had conducted the Workshop on AGC followed by feedback on

Ancillary Services implementation on 03rd

October 2016. Hon‟ble CERC had sought

comments on draft 5th

amendment to IEGC in which, creation of spinning reserve had been

proposed. The Final amendment in this regard was awaited.


NLDC had informed that a workshop on AGC was organized on 19th

/20th

Jan 2016. The

issue was further discussed in the FOLD Meeting held on 02.03.2016. It was discussed

in the Stake holders Meeting held on 15.03.2016 where all generators had participated.

NTPC, Dadri Stage-II was decided for Pilot Project keeping in view the high variable


cost, load center plant and since it is easy and economical to keep spinning reserve. LOA

for Dadri Pilot Project has been placed on 18th

Jan 2017 with time schedule of 4 months.

Other technical specifications, check list and consolidated rules for PLC Algorithm are

enclosed at Annexure-VII. Since this had commercial implications, the issue was being

discussed with NTPC, Dadri and Hon‟ble CERC would be approached for appropriate

orders. Though date for implementation was 01.04.2017, but being a new project,

Hon‟ble CERC had been approached appraising all the difficulties. It had therefore been

suggested that Pilot project would be taken up first and after getting experience and

submitting the report comprehensive AGC installation could be taken up.

To gain experience in SR, it was agreed that Pilot Project in SR for Simhadri St-II and N

P Kunta would be taken up.

In respect of N P Kunta, it was noted that POSOCO would get in touch with NTPC NP

Kunta for technical compliance to meet AGC requirements. For all plants, control

signals would be centrally transmitted from NLDC to the AGC software.

APTRANSCO had pointed out that subsequently, the matter would also be required to be

referred to APERC since it had commercial implications and RE had “must run” status.

MS, SRPC had informed that Hon‟ble CERC in its Order in respect of Petition No.

65/MP/2014 dated 13.2.2017 had stated the following:

„A detailed analysis of RRAS operation for the past 6 months has been submitted by the

NLDC in November, 2016 and the same is under consideration of the Commission. Based

on the experience gained from RRAS operations, POSOCO is expected to submit a

detailed procedure for implementation of Spinning Reserve of about 3,600 MW as per the

recommendation of the Committee on Spinning Reserve. Hence, in our view, there is no

requirement to engage an international consultant to study and recommend the road map

for introduction of constant frequency operation/secondary control.‟


8 CONGESTION RELATED ISSUES

8.1 NLDC had applied congestion charges on 14th

December 2016 for the 77-80 blocks. NLC

TS-II, NLC TS-I Expn, KKNPP, NTPL, NTECL and NTPC Stations (copy of letters

enclosed as Annexure-VIII) had informed that some of the notices such as Congestion

„Warning Notice‟, „Notice for Application of Congestion Charge‟ or „Notice for

Withdrawal of Congestion Charge‟ in line with Congestion Regulation / Procedure had not

been received by them in real time.

8.2 Clause 5.3, 5.6 and 6.5 of Detailed Procedure for Relieving Congestion in Real Time

Operation state as follows:

„5.3 Whenever actual flow on inter/intra regional link/corridor exceeds ATC and security

criteria as mentioned in clause 5.2 above are violated RLDC, NLDC may issue a

warning notice. In case, SLDC observes congestion within the intra State grid, it

shall inform the respective RLDC which in turn shall inform the NLDC. The notice

for congestion shall be communicated to all the Regional entities telephonically or

through fax/voice message/e-mail and through postings on website and making the


same available on the common screen at NLDC/RLDCs/SLDCs. The format of the

notice is enclosed as Format III.

…………………………………………

5.6 If violation of TTC limits persists for 2 time-blocks not counting the time-block in

which warning notice was issued by RLDC and no affirmative action is taken by

defaulting agency, NLDC/RLDC(s) shall issue a notice for application of congestion

charge. This notice shall be communicated to all the concerned Regional entities

telephonically or through fax message and through postings on website and the same

shall also be made available at the common screen at NLDC/RLDCs/SLDCs. The

format is enclosed as Format IV.

………………………………

6.5 Congestion charge shall be withdrawn after the power flow on the affected

transmission link/corridor has come down to the ATC and remains at this level for

one time block. NLDC/RLDC shall communicate to all the concerned Regional

entities telephonically or through fax message/e-mail and through postings on

website and making available the same on common screen available at

NLDC/RLDCs/SLDCs for lifting of congestion charge. The format of the notice is

enclosed as Format V.‟

8.3 Issue had come up for deliberation in the 127th

Meeting of OCC wherein Regional entities

had stated that Congestion charges should be waived off keeping in view the fact that a

number of entities had not received all relevant messages. KSEBL vide letter dated

21.01.2017 (Annexure-IX) had suggested for withdrawal of Congestion charges keeping in

view grounds mentioned in the letter.

8.4 SRPC Secretariat vide letter dated 30.12.2016 (Annexure-X) addressed to NLDC had sought

certain clarifications, as given below:

Criteria for declaring a region as upstream or downstream

ER schedule practicability

Total import capability Vs Congestion in a Corridor

Availability of Format III, IV and V at NLDC/SRLDC Website.

RRAS up during congestion for SR import

Tamil Nadu had not recovered from „Vardha‟ cyclone


NLDC had stated that whenever congestion charge is imposed, information is passed on

through mails and also by putting on website. Same procedure was also being followed in

other regions but there had been no such concern reported regarding receiving of messages

etc. Now, Formats had also been made available on NLDC website which could be

retrieved subsequently.

It was noted that issues such as under drawal in WR, over injection in WR, permitting

infirm injection, kicking in Ancillary up, impractical scheduling on ER-SR link and kicking

in congestion only for SR were some of the issues which need to be further deliberated. It


was also noted that only when messages were not being received by the entities, waiving

was being suggested. All other payments as per congestion account were being honored.

SRDLC/NLDC had pointed out that there was no provision for waiving off congestion

charges.

TCC recommended to waive off the congestion charges from 77 to 80 blocks on 14th

Dec.

2016 keeping in view the fact that applicable congestion notices had not been received by

generators/SLDC‟s in line with provision of CERC approved Congestion Procedure.

8.6 SRPC concurred with the recommendations of TCC.

8.7 Settlement of waived off congestion charge for the period 01.06.2015 to 07.06.2015

8.7.1 In the 28th

Meeting of SRPC held at Goa on 10.10.2015, it had been agreed to waive off

congestion charges for first week (01.6.2015 to 07.06.2015) of June 2015 as a special case.

It had been agreed that if charges are refunded by the receivable entity, it could be given

back to the entities, which made payments; else it would be adjusted in the future

congestion accounts.

8.7.2 In the 32nd

CC Meeting, SRLDC had requested the constituents to repay the congestion

charges amount to the Pool, so that the amount would be returned to the utilities that paid

the congestion charges. Otherwise, it may take considerable time to settle/adjust/repay the

congestion charges paid during 1st week of June 2015. CC forum suggested that the utilities

may consider paying back the amount received by them, as congestion charges for the

week 01.6.2015 to 07.06.2015, to the congestion pool account to enable

refunding/adjustment to the constituents, who paid congestion charges for that week.


KPTCL had informed that they had made the payment on 21.02.2017 to the congestion

pool account.

Status update is as given below:

S.NO Constituent Amount to be

returned to Pool

(Rs)

Status

1 Telangana 35,14,602 Paid

2 Karnataka 84,29,984 Paid

3 Goa 2,48,607 Paid

4 Kerala 67,72,148 Paid

5 NLC TPS-II (Expn.)-I

(Infirm) 1,43,979

Paid

6 NLC TPS-II (Expn.) 52,716 Paid

7 ILFS (Infirm) 69,126 Paid

SRLDC had informed that amount received from Karnataka had already been disbursed

(the statement in this regard is enclosed at Annexure- XI).



9 COMPLIANCE OF ORDER OF HON’BLE CERC IN PETITION NO. 420/MP/2014 –

IN RESPECT OF LVRT AND OTHER PROVISIONS OF CEA/CERC

REGULATIONS

9.1 Three Meetings had been conducted so far in compliance of Order of Hon‟ble CERC

(Petition No.420/MP/2014) in respect of LVRT and other provisions of CEA/CERC

Regulations. Hon‟ble Commission had specified time lines for a number of actionable points

for various entities.

9.2 Quarterly reports for the period January-March 2016 and April-June 2016 of the SR

constituents jointly validated by SRLDC/SRPC Secretariat had been communicated to

Hon‟ble CERC with regard to monitoring of the installation and performance of LVRT

installed on existing WTGs as per the directives of Hon‟ble CERC.

9.3 CEA had issued draft second amendment in CEA (Technical Standards for connectivity to the

Grid) Regulations and comments had been sought till 31.01.2017. This amendment seeks to

introduce/review the following provisions in the existing regulations:

a) Introduction of Frequency range with provision to include frequency response by

Wind & Solar power stations

b) Introduce applicability of LVRT to Solar Generating stations.

c) Change applicability of LVRT to Wind generating units/stations at all voltage levels

in place of 66 kV level & above.

d) Introduction of HVRT facility in Solar & Wind Generating units/stations

e) Specifying Ramp Up & Ramp Down rates for Solar & Wind Generating units/stations

f) Introduction of Voltage Regulation services for Solar & Wind Generating stations

g) Introduction of Short Circuit Ratio (SCR) for Renewable generating units/stations

h) Review of Reactive Power control capability of Renewable generating units/station

i) Review of limits of Harmonics

j) Review of limits of introduction of a new technology

k) Compliance Monitoring of CEA Regulations

The final amendment was awaited.

9.4 Quarterly report for the period July-September 2016 and October-December 2016 had been

communicated to Hon‟ble CERC.

9.5 SRLDC vide letter dated 07.02.2017 (Annexure-XII) had proposed the issue for discussion.


SRLDC had stated that new wind and solar units need to comply with LVRT/HVRT

provisions and STU/SLDC was to ensure necessary compliance. Required mechanism

needs to be in place for this purpose.

TCC had noted that it may be prudent to await second Amendment in CEA Connectivity

Regulations to move forward on the issue.



10 INCLUSION OF DRAWAL OF MAHE IN REA

10.1 In the 32nd

Meeting of CCM it had been decided that Mahe Region of UT of Puducherry

power drawl would be included in the REA of Southern Region from 7th

Nov 2016. KSEBL

vide letter dated 24.10.2016 (Annexure-XIII) addressed to PED had stated that KSEBL

would charge transmission charges for the intervening transmission facility at the rate as

determined by the KESERC, i.e. at the rate of 26 paise/kWh and also the losses in the

transmission system has to be taken into account. Further, it is also stated that a TSA needs to

be executed between KSEBL and PED. The matter had been taken up by SRPC (Annexure-

XIV) with KSEBL. Drawal by PED could not be included in REA from 7.11.2016. KSEBL

vide letter 24.12.2016 (Annexure-XV) communicated the following:

Willingness to allow UT of Puducherry to draw Central share to Mahe through REA at

transmission charges paid by KSEBL to other states but subject to approval of YTC by

Hon‟ble CERC.

CE, Tr (North) had been authorized to initiate necessary action to terminate the EHT

Agreement with UT of Puducherry after settlement of all dues/ arrears payable by UT

of Puducherry, on switch over of drawal of power to Mahe under REA.

They would be approaching SRPC for certification of the intra state lines of KSEBL

carrying power to Mahe as ISTS lines in terms of para 2.1.3 of Annexure-1 of Third

amendment of CERC Regulation.

10.2 UT of Puducherry vide letter dated 03.01.2017 (Annexure-XVI) had requested SRPC to

examine the above decisions made by KSEBL and advise accordingly. This issue had been

included as an agenda item in the 33rd

CCM. In the 33rd

CCM held on 31st January 2017,

Puducherry ED was requested by KSEBL to clear certain accumulated dues.

10.3 Secretary (Power), Puducherry vide letter date 07.02.2017 (Annexure-XVII) had proposed

to take up the matter in the ensuing 30th

TCC & 31st SRPC so as to get a consensus on the

issue and bring out the inclusion of Mahe region of UT of Puducherry power drawl in REA

at the earliest without any furtherance on the issue.

10.4 KSEBL vide letter 31.01.2017 (Annexure-XVIII) had stated that matter regarding

certification of intra-state lines of KSEBL carrying power to Mahe as ISTS lines be

discussed.


KSEBL had stated that the proposal of Puducherry was under consideration and further

details would be communicated in the SRPC Meeting.



10.7 CMD, KSEBL agreed with the SRPC Secretariat proposal in principle since it was in line

with the common philosophy being followed in SR for the beneficiaries. However it was

informed that formal approval of the Board would be obtained and subsequently

communicated.

11 ISSUES IN RESPECT OF NPCIL/BHAVINI

11.1 Delay in revision of DC and schedule of NPCIL units

Issue regarding delay in revision of DC and schedule of NPCIL units had been raised on

several occasions earlier. In the Special Meeting held on 25th

November 2016 after

deliberations, it had been agreed that NPCIL units would immediately inform SRLDC about

any tripping/synchronization in compliance of IEGC provisions and would also revise

DC/GS immediately. Changes in DC/GS would be communicated to SRLDC within

stipulated time frames. Necessary system/procedure would be put in place to ensure full

compliance. A workshop on grid aspect for NPCIL stations was also conducted by SRLDC

on 23rd

January 2017 at MAPS.


Station Director, MAPS (on behalf of all NPCIL units of SR) had informed that

implications had been noted by NPCIL stations of SR during the Special Meeting and

also further in the workshop conducted on 23rd

January 2017. Suitable instructions had

been communicated to all NPCIL stations of SR to take care of this aspect in future.


11.2 Black start mock drill for Nuclear Power Plants

In the Special Meeting held on 25.11.2016 and subsequent OCC Meetings, the following had

been noted:

KGS & MAPS had informed that during contingency, the units would go on house load

and they would be able to sustain for 6-7 hrs and subsequently, the reactor would poison

out. It would then take 36-38 hrs for revival. Subsequently, MAPS had informed that

they could operate on house loads only for two hrs. Success of going on house load was

very high but in the recent Vardha cyclone, Unit at MAPS did not go on house load.

Exact information was required to be suitably incorporated in the BSRP document and to

assess the need for black start mock drill for KGS and MAPS.

KKNPP had informed that their reactor does not have limitation of reactor poisoning and

the units could be brought back in short duration. During complete Black out around 50-

70 MW may be required per unit to meet the auxiliary consumption. SRLDC had

informed that procedure for extending supply to KKNPP during Black Out was in place.

It had been agreed that KKNPP would work out internal procedure to avail startup power.

Subsequently, mock drill would be planned and carried out in coordination with SRLDC

and TNSLDC.

SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed the issue for

discussion:



Station Director, MAPS had informed that low frequency set points would be retained.

High frequency set points for house load operation would be examined.

MAPS had agreed that during house load operation, it would synchronize even with

availability of single evacuation line. As per AERB guidelines, two sources are

required for synchronizing to the grid after criticality.

MAPS had agreed to look into the mock exercise during black start.

11.2.2 SRPC deliberations

SRPC noted the above.

SD, MAPS stated that 400 MW of power could not be evacuated through a single

evacuation line and hence TCC deliberations to be comprehended accordingly.

11.3 A/R for MAPS/BHAVINI lines

In the Special Meeting held on 25.11.2016, MAPS had informed that since line CVT‟s

are a pre-requisite for A/R, and replacement of 15 line CVT‟s were being taken up for

commissioning, A/R would be commissioned/ enabled alongside Y-ph line CVT‟s

replacement, and assured that A/R would be put into service in six (6) months time

(i.e., by May, 2017). They were in touch with TANTRANSCO, and had been assured

that 15 CVTs would be made available to them (as per mutually agreed terms and

conditions). Subsequently MAPS had informed that it is planned to get CVTs from M/s

TANTRANSCO by the end of February 2017 and implement the A/R for all the lines

emanating from MAPS by July 2017.

BHAVINI had informed that A/R would be enabled by January 2017.


discussion.


TANTRASCO had agreed to spare 4 numbers of CVTs to MAPS immediately.

Station Director, MAPS had informed that they required 15 numbers of CVTs and

requested TANTRANSCO to spare them. As committed earlier, they would comply

with CERC order in respect of providing of CVTs and would enable A/R by July 2017.

Parallely they had initiated action to purchase the CVTs. In respect of BHAVINI, the

requirement would be communicated for needful.



SD, MAPS again requested TANTRANSCO to kindly spare 15 CVTs so that the entire

work could be completed.

11.4 Status of 2 x 125 MVAR reactors at Kaiga GS

It had been noted that KGS / NPCIL would interact with SR-II PGCIL at the earliest

and come out with a detailed action plan by December 2016.

There was urgent need of reactor at KGS, and PGCIL could be requested by KGS for

diversion or providing spare reactor for KGS.



Station Director, MAPS had informed that financial sanction had been received in

this regard. Initially they would provide additional reactor and subsequently replace

existing reactor with 125 MVAR reactor. It could take around 2 years time for

commissioning of the reactors.

SRLDC had suggested that Kaiga GS could approach PGCIL to possibly utilize the

50 MVAR spare reactor available at Narendra.


PGCIL stated that they would not be able to spare the reactor.

11.5 Reactive requirement for KKNPP Phase-II unit

NPCIL had informed that they had taken up the issue with CTU (through email) and

reply was awaited.

SRPC & SRLDC had stated that the limitation of no absorption by Stage-2 units needs

to be taken up formally with CTU and details communicated to SRPC/SRLDC.


CTU had informed that NPCIL had not approached them on the above issue.

NPCIL was again requested to communicate MVAR absorption limitation to CTU at

the earliest.

It was noted that 2 bus reactors at KKNPP-I were under prolonged outage. SD,

MAPS had assured that the issues would be communicated to KKNPP for further

needful.


11.6 Planned maintenance of NPCIL Units

Keeping in view peak load period of SR, NPCIL had been earlier suggested to avoid

planning their shutdowns during the months of January to April each year. However,

it has been observed that one or two shutdowns invariably are availed during the

months of January to April each year. This year too shutdown of KGS unit-2 was

planned during December 2016 but subsequently rescheduled by KGS to February-

March 2017. SRPC Secretariat letter dated 06.12.2016 in this regard is at Annexure-

XIX. MAPS unit-1 shutdown which was planned for 29.11.2016 to 12.01.2017 had

been rescheduled to March 2017.

NPCIL needed to kindly plan unit maintenance during the period May to December

each year.


Station Director, MAPS had stated that maintenance of NPCIL units depended on

technical specifications and surveillance tests etc. A letter had been addressed to AERB

to permit extension of MAPS unit shutdown to 18.03.2017 and by that time Kaiga unit

would come back. To the extent possible, shutdowns would be planned during the

period May to December each year.



SRPC suggested NPCIL to plan shutdowns during May-December each year.

11.7 MVAR absorption at KGS

Issue of MVAR absorption had been discussed in the Special Meeting held on 25.11.2016

and the following noted:

KGS had informed that after unit-III generator core failure, generation was being

maintained at around 190 MW (to restrict the temperature). Core heating was being

observed in unit-IV also and therefore, they were restricting the MVAR absorption.

As a long term measure, they were planning to replace the generator itself.

Report of OEM about Unit III & IV Generator, clearly elaborating technical issues,

precautions etc needed to be furnished to SRPC/SRLDC. SRLDC vide letter dated

07.02.2017 (refer Annexure-XII) had proposed the issue for discussion.

SRPC/SRLDC/KPTCL had expressed concern and pointed out that KPCL/KPTCL had

completed the identified steps in the adjoining areas of KGS. KGS needs to be

proactive and commissioning of the 2 x 125 MVAR reactors needs to be expedited.

Other units should support the grid with MVAR absorption to possible capability.


SRLDC had expressed concern and stated that even Unit-IV was not absorbing

adequate MVAR , though the problem was with regard to Unit-III.

Station Director, MAPS had stated that both units were of same make and had similar

features and therefore, the MVAR absorption was being restricted. Report of OEM (on

restricting MVAR absorptions) would be shared.


11.8 Pending Protection issues specific to MAPS

Compliance of recommendations of PSAG-14 & PCSC-54 Meetings:

MAPS had been asked to furnish a report bringing out clearly actions taken w.r.t. the

recommendations given by PCSC forum in their 54th

Meeting held on 26.05.2016.

MAPS vide their mail dated 06.12.2016 sent compliance status, in which all

pending except A/R had been complied.

TANTRANSCO to kindly furnish status update on changing of porcelain insulators

with polymer insulators for each of the MAPS evacuation lines.

TANTRANSCO vide their letter dated 25.01.2016 informed that the long rod

insulation in 159 cut points out of 688 towers had already been replaced. On

23.12.2015 & 01.01.2016, replacement of insulators was made at 2 locations on

the 230KV Kalpakkam - S.P.Koil and on 05.01.2016 & 07.01.2016, replacement

work carried out on 230KV Kalpakkam - Acharapakkam feeder at 2 locations.

As about 2000 Nos. of insulators are to be replaced on all the 230 kV Feeders

emanating from MAPS to Kalpakkam, further replacement will be made after

procurement of insulators. TANTRANSCO vide their mail dated 22.02.2017


informed that so far 170 nos. of porcelain disc insulators had been replaced by

Polymer/ Long rod insulators by 20.02.2017


Station Director, MAPS had informed that around 50 % replacement of insulators with

Polymer had been carried out on MAPS evacuation lines. Some of the replacements

had been carried out using hot line techniques. Some of the tower base was corroding

and TANTRANSCO was requested to look into this aspect especially on SP Koil line.

TANTRANSCO had informed that insulator replacement was being taken up and

would be completed in couple of months.

It was noted that in addition to the insulators replacement, coping/

strengthening/replacement of towers may need to be carried out by TANTRANSCO.



TANTRANSCO agreed to take up the insulator replacement, coping /strengthening

/replacement of towers for MAPS evacuation lines and towers affected by Vardha

cyclone.

Status of providing Line CVT‟s in the Y phase of all feeders except SP Koil-2

MAPS representative had assured that said line CVT‟s erection & commissioning and

putting them into service would be completed in six to eight months, i.e., by July, 2017.


SD, MAPS had informed that the CVTs would be commissioned by July 2017.


11.9 Pending Protection issues specific to KGS

It had been decided that KGS would comply with all pending recommendations of

PCSC Meetings (47/II/7 & 57/I/1) in a week‟s time, and furnish a compliance report to

SRPC Secretariat.

KGS vide their mail dated 03.12.2016 had furnished compliance.

11.10 Monitoring of forced outage of 230 kV lines emanating from Nuclear Power Plants

Considering the security & importance of nuclear power plants, it was also decided that

SRLDC would monitor the trippings of all 220/ 230 kV transmission lines emanating

from all Nuclear Power Plants (viz., MAPS, KGS, Kudankulam NPP and BHAVINI

[from synchronization])

11.11 Metering Issues


SRLDC had expressed concern on persistent metering and data submission issues from

NPCIL units. For example Kaiga ICT data is not available since more than one year.

SD, MAPS had assured that concern in this regard would be communicated to all SR

NPCIL stations.


12 LOW VOLTAGES

12.1 SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed the issue for

discussion. Other issues with KPTCL/BESCOM were being deliberated in the OCCM.

12.2 Status of UVR implementation as finalized in the Special Meeting on Low Voltages held on

18th

April 2016 at SRPC, Bengaluru is given below please:

State Location identified

for implementation

Status of

implementation

Remarks

KPTCL Somanahalli 1st stage of 100 MW

implemented at

Somanahalli,

Nelamangala and

Hoody. Details of

2nd

Stage of 100

MW at Somanahalli

had been received.

Details for

Nelamangala and

Hoody were to be

received from

BESCOM.

In the 30th

SRPC

Meeting, KPTCL

had assured that UV

Relays at

recommended

locations would be

made operational

within three months

(by November

2016).

Nelamangala

Hoody

Bidadi It was agreed to drop

the Bidadi UVR

KSEBL Trichur Both the stages implemented

Palakkad

Kochi

TANTRANSCO Udumalpet Both stages implemented and in operation

from 30.11.2016.

Salem Both stages implemented.

Hosur


13 RELIABLE ALTERNATE AUXILIARY SUPPLY AT HVDC, BHADRAVATHI

13.1 Southern Region has a TTC/ATC of around 4,000/3,250 MW from WR. Out of this around

1,000 MW TTC/ATC is available through HVDC, Bhadravathi. Earlier Bhadravathi HVDC

station of PGCIL was having two feeders from MSEDCL (Maharashtra) and a back up DG.

The supply from MSEDCL had a number of voltage fluctuations and HVDC poles had

tripped on several occasions. There were some issues in the auto pick up/delayed pick up of

DG at PGCIL SS also. SR had been raising these issues since a long period. Subsequently,

PGCIL had gone for a 315 MVA ICT, the tertiary of which was used as alternate auxiliary

supply for PGCIL SS. After commissioning of this ICT, auxiliary supply reliability had

improved considerably.


13.2 In respect of Petition No.56/TT/2015 (dated 29.7.2016 ) Hon‟ble CERC had not approved

the 315 MVA ICT which was proposed to be used as an alternate supply to MSETCL and

had directed to remove the ICT as it is catering only 2 MVA load of HVDC, Bhadravathi. If

the ICT is removed, reliable uninterrupted supply to meet the auxiliary would be affected

and there could be more trippings of HVDC, Bhadravathi poles. Any tripping of poles leads

to diversion of power through other AC links (Sholapur-Raichur, Kolhapur-Kudgi etc) along

with all associated AC links in WR. Sometimes, it could lead to triggering of SPS affecting

the WR generators/SR loads. SR being an importing region is affected by such events.

13.3 In view of the above, WRPC had been requested to kindly consider the following:

Alternate EHV supply from MSETCL could be considered for reliable auxiliary supply

to HVDC, Bhadravathi.

MSETCL may be requested to have connectivity at 220 kV level from this ICT, if it fits

in their perspective plan. This would avoid shifting of this 315 MVA ICT.

PGCIL may be again requested to strengthen their auto pick up of DG which would

avoid tripping of the HVDC poles during any voltage fluctuation in MSEDCL feeders.

Any other option which could ensure reliable auxiliary supply to the HVDC,

Bhadravathi SS.


discussion.


MS, SRPC had brought to notice contents of Order dated 17.01.2017 of Hon‟ble CERC

in respect of Petition No 245/MP/2016. It had been suggested that the same could be

kindly examined by PGCIL

PGCIL had informed that they would provide ICT at Bhadravathi at their own cost.


14 DC FOR NTECL, VALLUR DURING VARDHA CYCLONE

14.1 NTECL-Vallur vide letter dated 28-12-2016 (Annexure-XX) had requested that, DC

during the period of shutdown of plant owing to Cyclone-Vardha, be allowed considering

declared capacity of 1,380 MW, which was prevailing, prior to the cyclone. It was stated

that the generation had been reduced due to “Force Majeure” conditions.

14.2 After deliberations in the 33rd

Meeting of Commercial Sub Committee, it had been decided

to put up the following for the approval of SRPC in the forthcoming Meeting:


Sequence of tripping of units is as follows:

Element

Tripping Time Restoration Time

Time Date Time Date

400 kV Vallur- NCTPC -1 1:05 12-12-2016 22:05 12-12-2016

400 kV Vallur- NCTPC -2 14:20 12-12-2016 16:05 14-12-2016

400 kV Vallur- Almathy -1 14:20 12-12-2016 11:09 14-12-2016

400 kV Vallur- Almathy -2 13:51 12-12-2016 12:35 13-12-2016

400 kV Vallur- Kalvindapattu -1 11:59 12-12-2016 15:43 13-12-2016

400 kV Vallur- Kalvindapattu -2 11:53 12-12-2016 14:45 14-12-2016

Vallur#1 11:09 12-12-2016 20:32 16-12-2016

Vallur#2 13:00 12-12-2016 1:34 15-12-2016

Vallur#3 9:36 12-12-2016 2:49 16-12-2016

DC may be allowed considering average DC for the past 7 days (with due consideration

of normal operation days). It may be allowed from the time block when first unit

tripped, i.e. Unit #3, from 09:36 hrs on 12.12.2016. DC may be allowed till 8 hrs from

time of restoration of last 400 kV transmission line (400 kV Vallur - Kalivandapattu

Line-2), which was at 14:45 hrs on 14.12.2016, i.e., up to 22:45 hrs on 14.12.2016.

NTECL-Vallur had stated that they could not come back on 14.12.2016, since port

clearance was not received to operate coal conveyer system till 15.12.2016.

It had been recommended that DC be revised to 1,250 MW as taking average of last 7

days (05.12.2016 to 11.12.2016). NTECL requested to consider the average DC

omitting the time blocks where unit tripped due to Steam leak turbine piping. The unit

was under outage from 18:38 hrs of 5th

Dec 2016 to 08:07 hrs 6th

Dec 2016.

Average DC works out to be 1,280 MW for the week starting from 5th

Dec 2016 to 11th

Dec 2016 excluding blocks from 18:45 on 5th

Dec 2016 to 08:15 of 6th

Dec 2016.

Commercial Committee recommended for Deemed DC of 1,280 MW from 09:30 of

12th

Dec 2016 to 22:45 of 14th

Dec 2016


TCC recommended for approval of SRPC, Deemed DC of 1,280 MW from 09:30 of 12th

Dec 2016 to 22:45 of 14th

Dec 2016 for NTECL in view of Vardha Cyclone. However, this

would not be cited as a precedence for any future cases.


SRPC approved the recommendations of TCC.

15 OUTAGE PLAN OF CENTRAL GENERATING STATIONS

15.1 APTRANSCOs suggestion on outage plan of CGS units

15.1.1 APTRANSCO vide letter dated 28.11.2016 (Annexure-XXI) had submitted the following:

Requested to take up with all Central Generating Stations of SR to complete the


overhauls of their units during July 2017 to September 2017, when wind potential is

expected to be higher during July to September.

Ensure full availability during the months January 2017 to June 2017.

Arrange to reschedule overhaul program of all CGS units during July 2017 to Sept

2017 and bring back the units on bar as per schedule.

15.1.2 The following had been noted in the 126th

Meeting of OCC:

NTPC/NLC had pointed out difficulty in carrying out maintenance during July –

September only due to contractual, availability of trained manpower, all India schedule

(NTPC), mining issues (NLC), simultaneous outages in same station, number of units

to be taken up for maintenance etc. Even 6 months were difficult to complete all the

maintenance.

SRPC/SRLDC had also endorsed views of generators and stated that 6 months were

required to complete the maintenance in phased manner between June to December.

The outages were being maximized during July to September. With higher ingress of

renewable more units would be required for hot/warm/cold standby to take care of

intermittency and variability. The peak demand was not substantially falling in July to

September compared to other months and for energy security optimal number of units

was needed as reserves.

After deliberations, it had been agreed that maintenance of thermal/nuclear stations

would be continued to be planned during June to December each year, maintenance

would be maximized during July-September while in October it would be optimally

minimized.


TCC had agreed that maintenance of thermal / nuclear units could be continued to be

planned during June-December each year. Maintenance would be maximized during

July-September by all generators while in October, it would be optimally minimized.


15.2 Information of unit revival of ISG stations /URS details

15.2.1 In the 126th

Meeting of OCC, TSTRANSCO had expressed that information on units likely

to revive up to next day needs to be made available by 10‟O‟ clock each day. It leads to

appreciable commercial loss since the power purchase gets affected due to lack of

information of unit revival. Issues on the information in respect of URS details in different

heads were also raised.

15.2.2 It had been noted that all generators need to diligently report the revival times which could

be incorporated in SRLDC report. SRLDC was requested to look into the possibility of

putting the URS details in different heads keeping in view the URS/scheduling which could

commence on D-2 day as proposed in IEGC amendment.


MS, SRPC had informed that it was noted that all generators need to diligently report

revival times which could be incorporated in the SRLDC report, since this had an impact

on power purchases.


TCC had suggested that generators may kindly inform revival times diligently to SRLDC

/ SLDC as applicable.


15.3 Deferment of approved outage plan for ISGS Units

15.3.1 In the 125th

OCCM, the following had been noted:

NTPC had expressed concern that unit maintenance was being planned diligently after

considering various factors by SRPC Secretariat. The schedule is getting affected due

to request of one of the constituent states. Lot of effort goes into planning and

preparation of unit outages and one rescheduling has a cascading affect on planned

maintenance of other units. There were contractual obligations and rescheduling leads

to intangible loss and stress to NTPC. For example, Simhadri unit went on forced

outage on two occasions as the planned outage was not approved. Number of unit

maintenance pile up towards Oct- Dec affecting the availability. The unit maintenance

gets rescheduled to periods where other states are facing deficit. The window to carry

out maintenance was also very small.

TANTRANSCO had expressed concern that number of maintenance was getting

accumulated and number of 500 MW units outage was getting overlapped.

SRPC had informed that outages are generally planned during June-Dec each year;

overlapping of more than two 500 MW is avoided. With the wind generation peaking

during June-September the outages is maximized during that period. The outages

quantum is computed on weekly basis and the outages are staggered to even out the

quantum during the agreed period. Rescheduling by one constituent completely upsets

the applecart. It has been observed in past that number of rescheduling was due to lack

of preparation and inadequate follow-up with OEM by generators.

After deliberations, it had been agreed that maintenance schedule would be adhered to

by all generators and states. Any request for rescheduling would be conceded only if

majority of states (3 out of 5) approve it, or else on directive of Higher Bodies like MoP

etc. Generators had been requested to be in touch with their maintenance agencies and

have periodical review Meetings to ensure that maintenance is carried out as per

programme. It was also desired by the forum that maintenance of nuclear units should

also be planned during June-Dec each year.


MS, SRPC had appraised about instances of rescheduling of outages of some ISGS units

at the request of one or two of the constituents. This was hampering maintenance

preparation of stations and at times outage was getting rescheduled to high demand

period of other constituents.

After deliberations, TCC had agreed on the recommendation finalized in the OCC forum.

Any request for rescheduling would be conceded only if majority of states (3 out of 5)

approve it, or else on directive of Higher Bodies like MoP etc.


15.3.4 Chairperson, SRPC observed that majority decision (3 out of 5) could affect states with

major share in the station.


15.3.5 After deliberations, SRPC concurred that if states having cumulative share of more than 50

% agreed for deferment, then alone the same could be agreed in contingency, or else on

directive of Higher Bodies like MoP etc.

16 EXPERIENCES FROM VARDAH CYCLONE

16.1 Vardha cyclone had struck Chennai and surrounding areas on 12th

December 2016. Its impact

on the grid and subsequent revival activities had been deliberated in detail in the OCC

Meetings. Some of the issues which require kind attention are given below:

SRLDC would firm up need for SAT Phone at critical sub stations/generating stations

specifically in coastal areas of AP/TN/ Puducherry. Other critical stations would also

be covered. SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed

the issue for discussion.

Reason for MAPS unit not going on House Load – MAPS needed to assess and revert

back.

Tripping of Almathy-Vallur lines on O/V (though the voltages were not high) –

TANTRANSCO/NTECL to revert back.

Adequacy of DG capacity at Almathy – TANTRANSCO to revert back. DG adequacy

needs to be assessed for all critical Substations/generating stations -TANTRANSCO/

TANGEDCO/TNSLDC/PGCIL/NTECL/MAPS to revert back.

Adequate manpower availability at SLDC/critical substations/generating stations in

anticipation to cyclone- TANTRANSCO/TANGEDCO/ TNSLDC/PGCIL/ NTECL/

MAPS to revert back.

Black Start Restoration Procedure needs to be reviewed/modified after case study -

NTECL/NCTPS/MAPS- SRLDC to revert back.

Any alternate means of SCADA data/voice communication availability during

contingencies –PGCIL/STUs to revert back.

TANTRANSCO to present detailed report - details of incident, problems encountered,

suggest improvements which could be adopted by all etc.

Readiness of ERS and other trained personnel/material which would be required for

restoration.


TANTRANSCO presented salient features in respect of Vardha Cyclone and also on the

restoration measures :

TNEB had met an all time high demand of 15,343 MW, thereby making Tamil Nadu as

second largest power consumption state in the Country. In and around Chennai, power

was being transmitted from generating stations through 400 KV and 230 KV EHT

feeders and distributed to the consumers through downstream lines.

On December 11th

2016, Indian Metrological Department, Chennai had issued an

emergency alert that Vardha cyclone would hit in and around Chennai, Kanchipuram

and Thiruvallur District of Tamil Nadu. Immediately under the guidance of Hon‟ble

Minister for Electricity of Tamil Nadu, an emergency Meeting was convened by CMD,

TNEB along with top Officials to discuss in detail about preventive steps taken to meet

out the emergency condition.


Men and materials were rushed to Chennai and placed at vital spots for quick

deployment at the shortest notice.

On December 12th

2016, Vardha cyclone struck Chennai and sub urban area causing

massive damages to the power industry.

As a result, 54 EHT towers, 296 Substations, 1835, 11 KV feeders, 32,100 Poles and

800 Distribution transformer collapsed.

Due to this 230 KV EHT feeders connecting Chennai through 10 transmission paths

snapped one after another, resulting in outage of all generating stations in and around

Chennai.

However, due to precaution measures taken by TNEB, there was no loss of life due to

electricity. To overcome this blackout, power was generated from the nearby Basin

Bridge Gas Turbine Power stations and 12 MW of power was evacuated immediately

through 110 KV EHT line to stabilize the grid. Immediately, supply was restored to

General Hospital, Secretariat and High court of Madras, Metro Water and Koyambedu

Bus Terminus. Further, healthiness of feeders was ascertained and supply was extended

step by step. Around 10:00 pm, 50 MW of load was met.

On December 13th

2016 around 3:00 am supply was extended to Chennai Airport and

flight service were resumed.

All EHT lines works were established by mobilizing gangs and healthy feeders were

restored in Chennai and resuming supply to Chennai was done step by step.

Due to the devastating effect of cyclone “Vardha” heavy wind had caused uprooting of

trees which fell on electrical infrastructure and caused extensive damages to electrical

poles, distribution transformers and conductors in Chennai, Thiruvallur &

Kanchipuram districts. Since the damages were very heavy and as it could not be

managed with the existing staff working in affected districts, workers from other

districts, labourers other than EB staff and 1,125 workers from Andhra Pradesh totaling

around 15,300 were deployed in restoration works and supply was restored at the

earliest though the damages were very severe.

Hon‟ble Minister for Electricity of Tamil Nadu, CMD of TNEB reviewed the

restoration activities with top officials on daily basis round the clock.

In order to replace the damaged poles apart from the stock of 32,000 poles, 10,000

additional poles were taken from Andhra Pradesh. 42,000 poles were transported and

restoration activities undertaken on war footing.

Labourers worked tirelessly round the clock to restore the damaged towers, poles and

electrical infrastructure towards restoration of power supply.

Due to dedication of Staff and Officers of TNEB and due to their extra ordinarily quick

response, power supply was put back on rails within very short span of time.

SRLDC had informed that communication was a major issue during the period.

PGCIL had informed that post Hud Hud cyclone and Srinagar floods, GoI had taken the

issue of reliable communication seriously and 6-7 Meetings have been held in this regard.

A Committee to look into reliable communication aspects had been formed.

After deliberations, the following was agreed:

An Expert Committee comprising of Communication Engineers including


representation from LD & C, PGCIL would study communication requirements for

ensuring data/voice to RLDC/SLDC during Natural Disasters.

DG Capacity requirement along with load would be studied by the entities and

compliance report would be submitted.

Coping and towers strengthening/replacement could be carried out by TANTRANSCO

(and other utilities) as per requirement.



ED (LD & C), PGCIL stated that representation from CEA would add value to the

Committee.

It was agreed that CEA would also be requested to represent in the Committee.

17 STATUS OF GENERATION IN ISGS

17.1 Issue regarding low generation at NLC TS-II Expansion, NTECL and NTPL had been

deliberated in the earlier Meetings of SRPC and subcommittee Meetings in which, the

following had been noted:

NTECL vide letter dated 10.11.2016 (Annexure-XXII) addressed to MCL had

submitted that realization of ACQ till date was only 69.8% of the pro-rate ACQ

resulting in drop in the ground stock and dependence on imported coal. Average rake

realization was only 2.77 rakes/day against the sanctioned programme of 4.4 rakes/day

for November 2016. The plant had been pro-actively taking many actions to overcome

the railway logistic bottlenecks in supply of coal like both Paradip & Dhamra Ports

have been engaged for coal receipt through Indian Railways and dispatch through sea

route, Panamax class vessels have been engaged to improve the coal off take and

manual uploading and intra Port transport facility maintained at Paradip to facilitate

receipt of BoxN type wagons from Talcher and Ib Valley. Subsequently, MS, SRPC

vide letter dt.16.11.2016 (Annexure-XXIII) had taken up the issue with MCL with a

request for increased dispatch of coal against FSA for NTECL to meet load demand in

Southern Grid. MCL vide letter dated 05.12.2016 (Annexure-XXIV) had pointed out

the issues with Railways/Ports and requested NTECL to impress upon various

Railways and Port Authorities to work on the constraints being faced and maximize

movement. In addition to the present movement, routes of Talcher-Paradip Port, Ib-

Dhamra Port and Ib-Paradip Port, it was suggested that NTECL should also explore

movement through Ib-Vizag Port, which would certainly be helpful for augmenting

coal movement further and especially when there was any constraint or congestion at

the other ports. TANGEDCO was already using this route gainfully. As per FSA, 5%

of ACQ is offered to all Power Houses on RCR mode and 5% of ACQ against import

component. NTECL may avail this coal under the respective dispensations to add up to

the existing materialization. NTECL vide letters dated 28.12.2016 & 21.01.2017

(Annexure-XXV) had taken up the issue of reporting of coal stock with CEA.

NLC had informed that they had narrowed down the issues which were related to

refractory etc and had carried out necessary modifications. They had achieved PLF of

49% in TS II Expn during July 2016. All issues were getting resolved and PLF of

around 75-80% was anticipated in the coming months.


17.2 Level of generation of some ISG stations is given below:


NTECL had informed that coal stock had been improved to 2.75 LT. They were making

all efforts to increase to 6-7 LT. Main issues were low coal supply at Talcher, availability

of rakes by railways at Talcher and Ib to transport coal to Paradip and Damra ports.

Coal was being supplemented from ECL/CCL. Imported coal supply would be stopped

shortly.

NLC had informed that refractory issue at TS-II expansion was being narrowed down and

that PLF would improve from March 2017 onwards.

TSTRANSCO had expressed concern on frequent force outages at NTPL. NTPL had

informed that due to entry of sea water into the boiler, the tubes were corroded. The

rectification was planned during April 2017 and July 2017 (U1/U2) respectively.

SD, MAPS had informed that as per request they were envisaging running the KKNPP

Unit-I on partial load up to 15th

April 2017, based on fuel availability.

TANTRANSCO had enquired whether NPCIL units (specifically KKNPP) can run on

flexible generation (generation levels could be controlled in a day). SD, MAPS had

informed that NPCIL units were base load stations and flexible generation levels may not

be possible.



17.5 Chairperson, SRPC observed that refueling of KKNPP units should be availed during lean

season and to avoid peak demand periods.

17.6 SD, MAPS informed that periodic refueling was to be taken up as per design. Unit-1 was

running continuously from February 2016 to November 2016. Unit-2 would be available to

full capacity after its COD. Proposed Generation schedule would be furnished for both the

units.

17.7 MCL representative stated that NTECL was being given additional coal from ECL & CCL

and supply from MCL would also be improved. On a query, he informed that there were no

coal supply issues at Ib, however rake issues persisted. Since coal stock at NTECL was

under critical category, MCL headquarters / CIL were taking necessary initiatives to

augment coal stock from other subsidiaries.

Station Aug’16 Sep’16 Oct’16 Nov’16 Dec’ 16 Jan’17

NTECL,

Vallur

Generation

in MU

893.17 859.46 709.30 797.95 788.38 880.32

PLF 80.03 79.58 63.56 73.88 70.64 78.88

NTPL,

Tuticorin

Generation

in MU

497.52 592.18 521.66 583.11 471.95 573.35

PLF 66.87 82.25 70.12 80.99 63.43 77.06

NLC TS II

Exp

Generation

in MU

61.10 156.85 85.53 23.20 157.11 164.21

PLF 16.43 43.57 22.99 6.44 42.23 44.14


17.8 Chairperson, SRPC stated that Coal stock of 4 days at NTECL was not comforting and

being a critical station, NTECL should have atleast 10 days of coal stock.

17.9 MD, KPCL pointed out that coal stocks position for KPCL stations at Raichur and Bellary

TPS was only for 3-4 days and had depleted considerably from earlier level of 20 days.

Coal movement from WCL and MCL had been patchy and issues at Talcher had already

been brought out. All bills of Coal companies had been cleared. Railways were suggesting

that they go for all RR route instead of RSR route.

17.10 MCL representative stated that there were no coal supply issues in respect of KPCL but

supply of rakes was not as required. They had taken up the issue with Railways and at

higher level with Director (Traffic), Railway Board to augment supply of rakes. They are

trying allotment of around 36-37 rakes to Ib Valley. Weekly, subgroup meeting was being

held in Delhi in which Railway (Joint Secretary Level), MoP and CEA officials were

deliberating coal stock/supply issues for critical and subcritical stations.

17.11 Chairperson, SRPC suggested that he would work out a joint meeting with Chairman, Coal

India, in which KPCL and NTECL coal issues could also be deliberated. Ideally, coal

stock should be maintained for around 15 days.

17.12 APGENCO confirmed that there were no coal related issues being faced by them presently.

They were having a coal stock of around one week.

17.13 It was agreed that a Meeting would be held at Hyderabad with participation of Coal India.

18 REVIEW OF ULDC / SCADA/COMMUNICATION

18.1 A Special Meeting had been conducted on 07th

February 2017 to deliberate on pending

SCADA/Communication issues (MoM available on SRPC website). Status of pending

items is as follows:

Issue Action Plan

1 Meeting with M/s

ALSTOM regarding

AMC issues, punch

points

Meeting was held on 16.11.2016 with M/s Alstom

and constituents and M/s Alstom had agreed to

liquidate all pending points except balance Training

modules by end of December 16. Approval for

recovery towards short supply of software has been

obtained by SRLDC while recovery proposal against

the contract of State constituents is under approval.

30th

TCC: SR-II, PGCIL informed that the rates for the unresolved points had

been firmed up and the recovery would be finalized. Only training was left which

would be closed by M/s Alstom and the same was scheduled in March 2017.

AP, TS & KER requested PGCIL to substantiate reasons for delay in completion

of new SCADA by M/s Alstom which had lead to the extension of the AMC by M/s

GE.


2 ICCP link between

RTAMC and SRLDC

ICCP link from RTAMC to SRLDC had been

established and database tables and ICCP association

was being carried out by RTAMC. This data can

form an alternate data set for all SR1 and SR2 data,

especially when data is unavailable or there is a

discrepancy.

3 KPTCL to Back up

SRLDC ICCP link

Link established and tested. ICCP association is

being made.

4 Data discrepancies in

ISGS/IPP/PGCIL/STUs

Sufficient number of Transducer spares needs to be

maintained as per usage/ replenishment.

To be addressed at the earliest. The schedule is given

in the MoM (07.02.2017).

30th

TCC: Sufficient number of spares needs to be maintained as per

usage/replenishment.

5 Replacement of

Transducer at NTPC

Ramagundam

NTPC confirmed that Transducer replacement work

would be completed latest by March 2017.

6 Providing additional

RTU at NTPC Talcher

RTU procurement is under progress and the same

would be completed by March 2017

7 Protection coupler

replacement for

Kayamkulam

Transmission system

SR-II informed that the expenditure on Protection

Coupler for Kayamkulam Transmission System needs

to be borne by respective beneficiaries.

8 Training on RTU

Maintenance

Training was completed 18.11.2016 at

Yelahanka/Hosur for all CGS and Regional entities of

SR.

9 Sparing of fibers in

TANTRANSCO links by

TANTRANSCO

SR II informed that consent was received from

TANTRANSCO.

10 NTECL fiber channel

connectivity

NTECL, SR-II & SRLDC would jointly coordinate

on 10.02.2017 for Vallur data integration at SRLDC.

SRLDC stated that they would ensure M/s Alstom

and SRLDC representative presence at

Sriperumbudur for end to end checking of DCPC.

SR-II would be ensuring presence of M/s Tejas at

NTECL.

11 OPGW stringing on

balance portion of

KPTCL lines

Forum suggested coordination between KPTCL and

PGCIL could be continued and pending works could

be completed to ensure path redundancy and

reliability to SRLDC.

12 Establishing E1 Link

between Backup SRLDC

to Backup NLDC

Link had been established on 05.12.2016 and

informed to SRLDC. Redundancy w.r.t SRLDC

control center hence is established. Back up Control

Center functionality was successfully completed on

31st January 2017.

13 Communication

Diagram/Connectivity

SR-I and SR-II informed that the Updated

Communication diagram / path for all RTU/DCPC

connectivity to SRLDC incorporating the latest

changes would be provided by end of February 2017.



14 Migration of SCADA

periphery in line with

SEM

Kerala SEM based drawal was checked by both

SRLDC and Kerala and was found satisfactory. The

same will be implemented in February 2017.

APTRANSCO, TSTRANSCO and PGCIL agreed to

attend to the issues at the earliest. Action plan would

be communicated to SRLDC/SRPC.

30th

TCC: AP & TS would migrate to SEM based drawals by 15.03.2017.

15 RTU data issue and

drawal differences w.r.t

APTRANSCO

SR-I and SR-II agreed to attend the issue on priority

and rectify as soon as possible. Daily verification for

drawal checking of states would be resumed at 11:00

hrs. Issues in drawls, if any, would be raised then and

will be rectified by concerned parties.

30th

TCC: PGCIL would rectify the data hanging issues for Raichur-Kurnool,

Kurnool-Thiruvalam and Chittoor-Thiruvalam by 15.03.2017. PGCIL would

replace the terminal equipment, if required.

Validation of drawal at 11 hrs to be continued.

16 SCADA Data failure

Protocol

RTU not reporting/data failure would be

communicated to the concerned entity/user with a

copy to PGCIL. User would take lead role in getting

the issue resolved. User/SRLDC would ensure

necessary verification at their ends as explained in the

training. Parallely, PGCIL would look into

communication issues. User/SRLDC would appraise

PGCIL about the verification at their end for PGCIL to

sort out the communication issues.

Official email ID for SCADA issues to be created for

each entity/User involved for easier communication

and proper delivery of information. All

correspondences regarding any SCADA issue to be

made through this mail ID only. Details to be

communicated to SRLDC/SRPC within a weeks‟ time.

17 Non-availability of

RGMO status /

Inconsistency in RGMO

data reporting to SRLDC

Generating stations and SLDCs agreed to look into the

issue and it was agreed that the issues would be

rectified by end of 15th

March 2017.

18 Integration of new

elements in

SRLDC/SLDC SCADA

All the concerned were requested to strictly adhere to

the time schedules

19 Issues with Orange

Exchange

A separate Meeting would be conducted by PGCIL by

end of Feb 2017 to resolve those issues. All

constituents were requested to communicate the

agenda point to PGCIL/SRLDC/SRPC to discuss the

hot line speech communication provided by Orange

Exchange.


18.2 Video Conferencing facility at SLDCs

Status update is as follows:

AP TN PUDU

Will provide the facility

in new SLDC at

Vijayawada by

March/April 2017.

VC facility between

SLDC (Chennai) and

SRLDC was established

on 19.01.2017. VC

between SLDC, SRLDC

and sub-SLDCs at

Madurai and Erode is

being tested.

Puducherry informed that

Budget for 2016-17 had

been approved but funds for

VC were not allocated due

to paucity of funds. They

would take up VC in the

next financial year 2017-18.

19 URTDSM (PMU) PROJECT IN SOUTHERN REGION

19.1 Hon‟ble CERC in its Order dated 16.09.2016 in the matter of „Approval …….. for grant of

regulatory approval for execution of Unified Real Time Dynamic State Measurement

(URTDSM) Phase-II‟ had stated

„22. It is noticed that URTDSM scheme was approved with the purpose to improve the

visibility and security and to mitigate the probability of grid failure. By considering the

present progress of the Phase-I, the petitioner does not seem to have made adequate efforts

to complete the phase-I of the scheme. The implementation period for phase-I was 2014-15.

However, it is still under implementation. We express our unhappiness with the progress of

Phase I of URTDSM scheme to be implemented by the petitioner. We direct the petitioner to

expedite the work of Phase-I of the scheme so that it may be completed by November 2016 as

submitted by the petitioner. Since substantial progress has not been achieved by the

petitioner in phase-I, it may not be appropriate to grant regulatory approval for

implementation of Phase-II of the scheme at this stage. Accordingly, the petitioner is granted

liberty to submit the fresh proposal for grant of regulatory approval for Phase-II of the

scheme in consultation with CEA after implementation of Phase-I scheme, which would be

considered in accordance with law.‟

19.2 Following is the status update in respect of URTDSM Phase-I as discussed in the Meeting

conducted on 07th

February 2017:

Sl. No. Issue Status/Remarks

1 Updated details of Nodal

Officers:

Whats App group in name of Southern Region

WAMS has been created on 03.11.2016. This

Group will look into dispatch, installation and

commissioning issues under URTDSM Project.

The above group would be functional during the

maintenance phase also.

2 Status of URTDSM

Project(SR Portion)

PMUs to be installed in SR as per URTDSM

Project Package–II had further increased from 240

to 264 on account of commissioning of certain

new stations and additional feeders. (As per LOA-

212)


Status

Total

Envisaged

Survey

completed

S/S PMU

SS PMU Installed

SR

I

120

Pending in

Hyderabad,

Khammam

and Vemagiri.

PMU quantity

would be

finalized by

end of Feb

2017

18

74

SR

II

41 144 Completed 28 91

Remaining 52 PMUs as per revised BOQ (out

of 264) would be supplied once rate

negotiation with M/s GE is completed.

Currently a Committee is formed by LD&C

PGCIL for rate finalization as extra PMUs are

exceeding the overall quantity variation of SR

& WR limit of 15 % as per original LOA.

Forum requested Project Coordinator/PGCIL to

freeze the total number of PMUs for SR at the

earliest in the interest of faster execution of

project as in the previous Meeting the number

of PMUs had been revised to 240 from 212(as

per LOA). Additional requirement could be

covered in Phase II.

Forum expressed concern that project was

getting delayed and requested PGCIL / GE to

share monthly project execution plan up to

Sep 2017 and monthly progress (

installation and integration to Control

Centre) status by end of every month.

30th

TCC: PGCIL informed that Control Centre hardware has reached Mumbai

and FAT would be completed by March 2017 while SAT would be completed by

April/May 2017. This project would be completed by September 2017.

TCC suggested that Phase-I of the URTDSM project needs to be completed at the

earliest.

PGCIL requested the entities to work out and intimate requirement for Phase-II of

the URTDSM project. They were planning to approach Hon‟ble CERC in April

2017 again.

3 Contractual amendment

Negotiation is under progress with GE T&D.

Amendment is expected to be released in

April’2017 (last Meeting agreed for January 2017)

and system expected to be commissioned by Sep

2017.


4 Requirement of Auxiliary

Power Supply System (APS)

as per revised BOQ

(excluding input ACDB and

one battery bank of the

proposed two battery banks).

SRLDC had already intimated to SR-II vide

letter dated 12.12.16

APTRANSCO, TSTRANSCO and

TANTRANSCO confirmed the requirement of

Auxiliary Power Supply System, a letter

confirming the same would be furnished to SR-

II within a weeks‟ time.

SR-II informed that once all constituents

finalized the APS System requirement by 15th

February 2017, the revised BOQ of APS would

be furnished by LD&C, PGCIL.

It was noted that KSEBL and KPTCL had

already confirmed in the previous review

Meetings that they do not require APS System.

APS System was expected to be delivered

during the month of May 2017. All constituents

were requested to make site ready for APS

System installation to avoid further delay.

5 Capacity of Battery & charger KSEBL suggested to have clear SAT procedure

with current limiting and constant voltage

charging as stipulated by OEM of VRLA

battery set.

6 Responsibilities under Entities SR-II confirmed that dismantling of panels and

any civil works etc required to prepare site for

installing APS System was not under the scope

of the Project and thus was in the scope of

respective constituents.

Supply, erection & commissioning of UPS,

ACDB Input & Output panels, Battery Bank

and associated cabling works for establishing

APS system was under the scope of the Project.

Air Conditioning System was required and

constituents were to make necessary

arrangements.

7 Redundancy for PMUs PGCIL confirmed that all PMUs are provided

with redundant communication path and

schematic diagram of communication flow had

been shared with the constituents.

8 SAT procedure Draft SAT procedure had been circulated

among all constituents. SAT in SR earlier

planned for January 2017 was postponed to

April 2017.

9 SR Region Training

Training had been firmed up by M/s GE and

will be conducted in two batches starting from

27th

February 2017. The details of module have

been communicated to all. Training would be in

two phases and it would cover both operation

and maintenance aspects.

10 Availability of necessary

communication ports for

All constituents to make available necessary

communication ports for connection of servers

under URTDSM project by 20.02.2017 as


connection of servers under

URTDSM

decided in the last Meeting.

11 Training on Application part PGCIL (LD & C) had stated that requirement of

Training on Application part would be

communicated to the Management

30th

TCC: PGCIL informed that out of six analytics, three analytics prototype were

under trial operation at WRLDC and also in Gujarat system. PMUs in Gujarat

were to be integrated with the PMUs of URTDSM project and analytics could be

uploaded for trial operation at Gujarat SLDC also.

31st SRPC: PGCIL informed that three analytics prototype were under testing at

Delhi and in March 2017, they would put be under trial operation in WRLDC.

Gujarat had commissioned 110 PMUs on their own and they were to be integrated

with URTDSM project and analytic test could be taken up subsequently.

12 Update the Drawings Constituents‟ requested PGCIL to update the

Drawings with changes done in the

CT/PT/Status wiring for the PMU system and

submit as built drawing.

13 Completion of the

commissioning activity at

each site.

M/s Alstom and PGCIL representatives were

requested by constituents to certify the

completion of the commissioning activity at

each site.

14 Mandatory spares PGCIL had agreed to furnish the details about

the mandatory spares supplied at each site.


20 SCHEDULING OF WIND & SOLAR GENERATING PROJECTS HAVING

CAPACITY OF 500 MW AND ABOVE

20.1 Hon‟ble CERC vide amendment dated 7th

August, 2015 (Indian Electricity Grid Code - Third

Amendment) Regulations, 2015, which came into effect from 1st November, 2015 had

amended the following:

Amendment of Regulation 6.4 (2) of Part 6 of Principal Regulations which is read as:

“The Following generating stations shall come under the respective Regional ISTS

control area and hence the respective RLDC shall coordinate the scheduling of the

following generating Stations:

b) Ultra-Mega Power projects including projects based on wind and solar resources and

having capacity of 500 MW and above”

20.2 It had been requested that details of upcoming wind and solar projects with installed capacity

of more than 500 MW may kindly be intimated to SRPC.


MS, SRPC had requested constituents to share the details of wind and solar projects

having installed capacity more than 500 MW which would assist in ensuring technical /

commercial requirement as per CEA/CERC Regulations and also seamless integration

and accounting by SRLDC / SRPC.


APTRANSCO had expressed concern that if the scheduling responsibility is shifted to

SRLDC, it would be difficult for APSLDC to manage DSM deviations considering intra-

day and seasonal variations of load and RE injection. During the months of July to

August, availability could be around 12,000 MW while demand would vary from 5,500

to 7,000 MW. About 1,600 MW of overhauls were planned and thus even after backing

down there could be need for some curtailment of RE also as a last resort.

TCC had observed that the requirement emerged from CERC Regulations and

APTRANSCO could appropriately take up the issue.


20.4 APTRANSCO again expressed concern over scheduling responsibility being shifted to

SRLDC for RE projects (more than 500 MW) since during any contingency, they would not

have any control over these generators. STU connected generators need to be scheduled by

respective SLDCs. It required 45 minutes to make correction in schedules as per Regulations

in place and during this period; grid security could get endangered besides state getting

commercially penalized also.

20.5 Chairperson, SRPC stated that any load/generation management would require to be carried

out by Discoms. Being regulatory associated; the issue had to be dealt appropriately.

20.6 APTRANSCO was suggested to approach appropriate Commission on the issue, if deemed

fit.

21 ISSUES IN RESPECT OF CONNECTIVITY/LTA/LILO/INFIRM POWER

21.1 Hon‟ble CERC in its Order dated 28.09.2016 in respect of NLDC Petition No. 30/MP/2014

had passed the following Order:

„(a) CTU is responsible for planning and coordination with regard to inter-State

transmission system in consultation with all concerned as mentioned in Section 38 (2) of

the Act for development of efficient, conducted and economical system of development of

transmission system for smooth flow of electricity from the generating station to the load

centre. CTU is also responsible for providing non-discriminatory open access to the inter-

State Transmission System for use by any licensee or generator or consumer (subject to

permission by the State Commission). Therefore, while planning and developing the inter-

State Transmission System, CTU is required to take into consideration the applications for

connectivity and LTA received in accordance with Connectivity Regulations.

(b) CTU shall plan the inter-State Transmission System after carrying out the system

studies in accordance with CEA Connectivity Regulations. If on the results of the study it

appears to the CTU that connectivity is required to be granted by looping in and looping

out the existing or proposed transmission line, CTU shall include such LILO as part of the

coordinated planning and development of the inter-State Transmission System.

(c) Injection of infirm power and/or drawl of start-up power may be allowed in the interim

arrangement through LILO by RLDCs in accordance with the relevant provisions of the

Connectivity Regulations and Grid Code, keeping in view the grid security. If more than

one generator is injecting infirm power or drawing start-up power within the same

timeframe, then the concerned RLDC shall finalize schedule after discussing the same in

the Regional Power Committee in order to ensure that such unscheduled inter-changes on


account of injection of infirm power/ drawl of start-up power do not endanger grid

security.

(d) Injection of firm power shall not be allowed as a matter of principle. In exceptional

cases where the dedicated transmission line executed by the generator/ CTU/ inter-State

transmission licensee is unlikely to be commissioned matching with the COD of the

generating station or a unit thereof, concerned generator/ CTU/ inter-State licensee shall

be required to approach the RPC of the respective region three months prior to the

anticipated COD of the generating station for continuation of the LILO arrangements for

injection of firm power. The RPC in consultation with CTU after considering the proposal

in the light of the relevant factors can permit injection of firm power for a period of three

months which can be extended for another period of maximum three months. If the

dedicated transmission line is not commissioned within the period granted by the RPC,

then interchange of firm power shall not be permitted by the RLDC concerned on interim

LILO arrangement.

(e) CTU shall take up all the existing cases of connectivity on interim LILO with the

RPC of respective regions within a period of one month from the date of issue of this

order for review and decision on disconnection of the interim arrangements through

LILO. All such interim arrangements through LILO shall be disconnected within a

period of three months of the issue of this order unless the RPC grants extension for

continuation of LILO keeping in view of all relevant factors.

(f) As far as practicable, intra-State generating stations should not be granted interim

connectivity to ISTS for drawing start-up power or injecting infirm power. Only in

exceptional case, interim connectivity to intra-State generating stations may be granted on

the basis of explicit recommendations by the concerned STU.

(g) CTU shall review all cases where LTA taken by the generators have not been

operationalized on account of non-commissioning of the dedicated transmission line or

some of the system strengthening lines, even though the generators have been permitted to

inject firm power on short term basis. Based on the review, CTU shall operationalize the

part/full LTA in respect of the transmission lines which have been commissioned and raise

bills for transmission charges on the generators concerned.‟


22 TTC/ATC


In the 4th


December 2015 (MoM dated 1.1.2016), 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.

Converged PSSE base cases to be furnished to SRLDC.

SRLDC had stated that intra-state TTC/ ATC computations could also help in transfer of

power among SR-Constituents and they would render full assistance in this regard. For

instance, TN power could be sold to Telangana during the months of June-September.

There were constraints in WR and ER towards NR but there were no constraints in SR.

Constituents had been requested to nominate officials to coordinate with SRLDC to

identify these trading possibilities so that it would be commercially beneficial to all. All

states need to host ATC/TTC computations on their websites


CEA had stated that intra-state ATC/ TTC computations were very much essential to

implement GoI initiative of Discovery of Efficient Electricity Price (DEEP). In DEEP

platform, certain transactions were cleared but could not be materialized due to TTC/ATC

limitations. States need to furnish ATC/TTC computations, long term, medium term and

short power purchase agreement/plans and procurement through this platform. This would

help in reducing the cost of power purchase and uphold transparency. ATC/TTC

computations transparency has been achieved at CTU/RLDC level and same has to be

achieved at state level to ensure that all are on same platform.

Director (G & TM), APTRANSCO had assured that despite manpower shortage, they

would nominate some officials to get trained for ATC/TTC computations.

22.2 The following is the status in this regard:

State 5

months

LGB

Converged

PSSE Base

case

ATC/TTC

Computation

furnished to

SRLDC

ATC/TTC

Computation

posted on SLDC

website

Nodal

Officer

Status

Study

Group

AP Yes No No No No No

TS Yes Yes No No Yes Yes

KAR Yes Yes No No No Yes

TN Yes Yes No No Yes Yes

KER Yes Yes No No Yes Yes

Pudu NA No No No Yes No


SRLDC & SRPC had expressed concern that number of activities as enumerated in the

Table above were yet to be complied by entities. All concerned entities had been kindly

requested to initiate action to comply with the above.


22.4 SRPC suggested for concerted action from the concerned for compliance of the above.

Nodal Officers details, wherever pending , was to be communicated to SRLDC & SRPC

by 15th

March 2017.

22.5 Revision of TTC between S1-S2 and formation of S1-(S2&S3)

22.5.1 The following issues had been raised in this regard:

TTC between S1-S2 got revised from 7,382 MW to 5,426 MW for the months of

December 2016 vide revision No.1 issued on 29th

November 2016. Reason for revision

was mentioned as limiting constraints getting shifted from (N-1) contingency for 400

kV Hiriyur-Nelamangala D/C to (N-1) contingency of 400 kV Udumalpet-Palakkad

D/C

KSEBL had stated that declaring Kerala as separate control area (S3) needs to be

deliberated in RPC forum.

No of correspondence had been exchanged by KSEBL, TANTRANSCO, SRLDC,

NLDC & SRPC secretariat (copies attached with OCCM) on this issue.


NLDC on 30.12.2016 had formed S1 – (S2&S3) with TTC of 6,720 MW & S3 with

TTC of 2,900 MW.

TANTRANSCO vide letter dated 05.01.2017 (Annexure-XXVI) had raised certain

observations on the above and had stated that split bus arrangement should not hamper

the existing load pattern in TANTRANSCO network. It was suggested to provide

necessary SPS arrangement to restrict the overloading of feeders at Meywdai,

Checkanoorani and Tirnulveli 400 kV SS. A special system study Meeting was

requested to be convened in this regard. SRPC vide letter dated 06.01.2017 (Annexure-

XXVII) had furnished the clarifications to TANTRANSCO.

KSEBL vide letter dated 03.01.2017 (Annexure-XXVIII) had raised certain

observations in respect of PSSE base case for January 2017 and requested that TTC

declaration may be revised by the removing creation of S3. SRLDC clarification vide

their mail dated 05.01.2017 is given at Annexure-XXIX.

NLDC vide letter dated 23.01.2017 (Annexure-XXX) had informed about

operationalization of new bid area S3 wef 24.01.2017 for delivery date 25.01.2017.

KSEBL vide letter dated 31.01.2017 (refer Annexure-XVIII) had stated that formation

of S3 bid area and issues relating to partial commissioning of assets be discussed. The

proposed formation of S3 area has been proposed to be reviewed.


22.5.3 It was noted that a Meeting had been conducted on 17th

February 2017 to finalize SPS to

contain possible over loading of upstream elements of 220 kV Idukki-Udumalpet and

Sabarigiri-Theni lines due to split grid operation in Kerala system (MoM available on

SRPC website). SRPC Secretariat had thanked both TANTRANSCO and KSEBL for

coming to a mutual consensus on the issue of SPS.


22.6 Revision of TTC/ Curtailment to Southern Region

22.6.1 KSEBL vide letter dated 21.01.2017 (refer Annexure-IX) had expressed concern over

conservative approach for the determination of ATC-TTC of the region and downward

revision of TTC imposing restriction on import by KSEBL. Commercial impact on

additional purchases on account of such curtailment of Rs 7.50/unit. KSEBL had

requested that any curtailment of corridor was to be judiciously done by POSOCO; any

work has to be completed in the minimum possible time by PGCIL and the revival has to

be declared realistically so as to facilitate minimization of curtailment.

22.6.2 SRPC Secretariat vide letter dated 24.11.2016 (Annexure-XXXI) had invited attention

of NLDC to CEA‟s letter dated 22.11.2016 and deliberations in the 40th

Standing

Committee Meeting of SR held on 19.11.2016, wherein, it was agreed that the loading

limit of Raichur-Sholapur 765 kV 2xS/C can be enhanced from 2,500 MW to 2,750 MW


(under N-1 condition). Studies indicate that TTC to SR could be enhanced by 400 MW

i.e. from 6,650 MW to 7,050 MW.

22.6.3 Subsequently, it was noted that the TTC had been increased for 7 hours a day while

LTA/MTOA had increased from 3250 MW to 3384 MW for 24 hours.

22.6.4 KSEBL vide letter dated 31.01.2017 (refer Annexure-XVIII) had stated that POSOCO

may follow approved procedure for computation of TTC. KSEBL had stated that

POSOCO is curtailing TTC heavily when shutdown is availed on bus bars of Sub-station.

Similarly, S1-S2 ATC is seen reduced when one ICT is taken for shutdown without

considering the fact that 220 kV distribution may be possible even otherwise, without

affecting 400 kV line flows.

22.6.5 KSEBL vide letter dated 23.02.2017 (Annexure-XXXII) had stated that 500 MW

additionally created on Talcher-Kolar HVDC link with capital inclusion earlier is kept as

reserve to control the flow on AC lines. It was suggested to release of 500 MW for 10 hrs

which may be considered in ATC/TTC computations.


It was noted that with commissioning of Angul- Srikakulam- Vemagiri corridor, the net

increase in TTC was only around 200 MW (+800 MW on ER-SR and - 600 MW on

WR-SR). Taking SPS into consideration for TTC computations is supported by

provisions of IEGC as well as by CAC‟s recommendations approved by Hon‟ble

CERC. SPS logic presently configured for tripping of Aurangabad-Sholapur D/C lines

could be modified to tripping of S/C line and TTC could be computed accordingly.

After deliberations, the following was noted:

NLDC was suggested to revive TTC/ATC of 500 MW for 10 hours on Talcher-Kolar

HVDC which had been earlier operational (prior to commissioning of Raichur-

Sholapur link).

It was observed that constraint for import of power from NEW grid would be

Vemagiri- Gazuwaka line with the worst credible contingency of N-1 of 765 kV

Aurangabad-Sholapur line. TCC suggested NLDC to consider the SPS on 765 kV

Aurangabad-Sholapur D/C line (could be modified for tripping of one circuit of

Aurangabad-Sholapur) while selecting the worst credible contingency for assessing

TTC to SR.

Regarding, KSEBL issue it was noted that issue regarding curtailment of TTC due to

shutdown of bus had been taken up by SRPC Secretariat with NRCE. Other specific

issue of TTC curtailment for ICT shutdown etc could be deliberated in the

subcommittee Meetings.


22.6.8 CMD, KSEBL stated that Kerala was undergoing severe drought and thus 10 hrs of

additional ATC on Talcher-Kolar HVDC link was needed to be released urgently. It

would be very useful for them during the summer.


22.6.9 NLDC stated that this 500 MW capacity was being used to control the flows.

22.6.10 MS, SRPC noted that now there were three links in parallel with the HVDC link and

thus sensitivity on Raichur-Sholapur link with Talcher- Kolar HVDC flow change had

thus naturally decreased compared to earlier.

22.6.11 SRPC suggested NLDC to study the proposals of TCC. NLDC stated that they would

examine the proposals and revert back.

22.7 Planned shutdown of Talcher-Kolar HVDC link

22.7.1 In the 128th

OCC, the shutdown of Talcher-Kolar HVDC link had been agreed from 4th

-8th

March 2017.


In the Meeting, SRTS-II, PGCIL had informed that on account of non-availability of

experts /OEM from Germany, the shutdown was now planned during 6th

-11th

March

2017. Shutdown was critical in nature and was to be attended immediately as explained

in the sub-committee Meetings.

In view of non-convergence on the matter, it was agreed to deliberate the proposed

outage further in the SRPC Meeting.

TCC had categorically pointed out that in future at least PGCIL / Transmission Licensees

(of critical inter-regional and intra-regional links) should plan and complete maintenance

during June to December (in contingency only could be extended up to 20th

January) each

year so as to ensure that elements affecting TTC/ATC of SR, S1-S2 & S3 are available

during the peak months of February to April each year.


22.7.4 GM, SR-II, PGCIL appraised SRPC of the requirement of the critical shutdown during this

period. The work involved insulator replacement in three regions, OLTC capital overhaul

and pole related works at both Talcher and Kolar ends. During day time, both poles would

be out since both the lines will be out. During night time, they would be bringing back one

of the poles except on two nights when both poles would be out.

22.7.5 SRPC stated that PGCIL should endeavour to bring one of the poles during evening peak

hours from 1730 hrs on each day.

22.7.6 CMD, KSEBL stated that March was a critical month for them being exam period and

shutdown of this nature needed to be avoided in future.

22.7.7 ED, SR-II, PGCIL informed that they had tied up with M/s Siemens this year with limited

leverage and the condition of the link was critical. From next year onwards, shutdown

would be taken up before December/20th

January.

22.7.8 APTRANSCO opined that it would be prudent to go for planned shutdown rather than face

any forced shutdown.


22.7.9 SRPC concurred for the shut down as a special case. It also concluded that a TCC

recommendation as given below was to be complied in future:

PGCIL / Transmission Licensees (of critical inter-regional and intra-regional links) should

plan and complete their maintenance during June to December (in contingency only could

be extended up to 20th

January) each year to ensure that the elements affecting TTC/ATC of

SR, S1-S2 & S3 are available during the peak months of February to April each year.

22.8 Furnishing of Tripping files (FIR/DR/EL/TR) for forced outage of Inter-Regional

Grid-Elements

22.8.1 Since healthy working condition of grid elements and fail-proof operation of protection

systems in place are sine qua non of secure and integrated operation of grid, it is but

essential that a close vigil is maintained on the trippings of grid elements. To facilitate

this, whenever tripping of any grid element takes place, relevant tripping files

(FIR/DR/EL/TR) are being sought from concerned Constituents to carry out systematic

tripping analysis and identify suitable remedial measures to be taken to avoid recurrence

of such events in future.

22.8.2 Timely submission of tripping files is mandated by Regulation 5.2 (r) of IEGC, as per

which all Users, Utilities, STU/ SLDC and CTU are required to furnish for analysis

purpose the relevant information relating to tripping events in their system along with

Disturbance Recorder (DR) and Event Logger (EL) to RLDC/ RPC within 24 hrs of

occurrence of the same. No User, SLDC/STU or CTU shall block any data/information

required by the RLDC and RPC for maintaining reliability and security of the grid and

for analysis of an event.

22.8.3 Though this has been religiously pursued for all kinds of forced trippings, instances of

delayed or non-furnishing of sought tripping details have been witnessed more frequently

in case of trippings involving inter-regional grid elements, owing to their being in

different operational jurisdiction.

22.8.4 This particular issue of timely reporting of inter-regional grid elements had also been

discussed in the 11th

Meeting of Protection System Analysis Group (PSAG-11) of SRPC

held on 24.01.2015 at HVDC, Bhadravathi, when the following was agreed upon:

Reporting of events of tripping by Bhadravathi

SRLDC is maintaining a web portal for submission of DR/EL/TR of any

tripping/event by the utilities of SR. SRLDC will provide user Ids for WRTS-I

and Bhadravathi S/S to post the DR/EL/TR of any tripping at Bhadravathi &

POWERGRID Stations of WR – SR links within 24 hours on this web portal.

SRLDC will also share the web application package with WRLDC to facilitate

creation of similar web portal to get the details of any event by WRLDC.


22.8.5 Subsequent to this Meeting, User-ID‟s and Password‟s had been provided to WRTS-I and

Bhadravathi S/S by SRLDC for uploading required tripping files. However, timely

furnishing of required information necessitated by tripping of WR-SR links was observed

to be not satisfactory in majority of the cases. Recent trippings of HVDC Bhadravathi

Pole-1 on 02.12.2016 and 19.12.2016 are a case in point. PGCIL was therefore kindly

requested to ensure compliance of above mechanism by WRTS.

22.8.6 Similarly, in view of newly commissioned/ upcoming links of SR-ER, PGCIL was also

requested to ensure posting of tripping files (FIR/DR/EL/TR) by their ER counterparts of

any tripping of SR-ER links within 24-hr on SRLDC web portal, for which separate

User-ID and Password would be given.


MS, SRPC had appraised TCC of the requirement to have tripping files of WR and ER

contiguous S/S which assisted in analysis of events in the Meetings of PCSC. PGCIL

was requested to take up the issue suitably with WRTS & ERTS for uploading relevant

tripping files on SRLDC web portal.

PGCIL had assured that they would take up with WR and ER counterparts to comply

with Regulation 5.2 (r) of IEGC in furnishing relevant tripping files (FIR/DR/EL/TR)

relating to trippings of SR-ER and SR-WR links in SRLDC web-portal. SRLDC was

requested to kindly provide User-ID and Password to ERTS-I, PGCIL for uploading the

required tripping files.


23 UPCOMING TRANSMISSION SYSTEM

23.1 In the 30th

Meeting of SRPC, it was noted that a Committee for finalization of compensation

in regard to Right of Way (RoW) for transmission lines in urban areas had been constituted

by MoP vide OM dated 11.08.2016. Principal Secretaries of Karnataka and Kerala from

Southern Region were also Members of this Committee.

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

Sholapur line (Out of planned 18 elements)

23.2.1 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

Power flow of around 550

MW observed with temporary

reconfiguration at Bidadi SS.


23.2.2 In the earlier Meetings, following had been noted:

SR-II, PGCIL had informed that there was not much progress in three districts, Bengaluru

Urban, Bengaluru Rural and Tumkur. Only 5 km of stringing work was pending in

Tumkur-Yelahanka line.

KPTCL had informed that Govt of Karnataka was seized of the issue. Recently, Hon‟ble

Chief Minister had reviewed the matter and directed the concerned to deploy police force,

wherever required. With directives from the top, they were hopeful that issues would be

resolved at an early date. KPTCL had informed that Additional Chief Secretary had also

intervened in this matter.

PGCIL had informed that in recent orders, Hon‟ble CERC had directed that transmission

charges are to be paid by state utilities, in case downstream network is not ready. In the

recent Grid Code Amendment, the Commission has stated that there has to be an

Implementation Agreement between the respective state and PGCIL. Firm dates for

downstream evacuation system at Madhugiri and Yelahanka needs to be confirmed by

KPTCL for proper coordination.

23.2.3 Hon‟ble Commission in its ROP dated 15.12.2016 in respect of Petition No 54/MP/2016,

IA No 48/2016 & 403/TT/2014 had stated

„3. The Commission observed that comments sought vide letters dated 7.11.2016 and

28.11.2016 from CEA have not been received. The Commission directed the staff of

the Commission to study the comments furnished by SRLDC and to seek the comments

from SRPC on the PGCIL‟s contention that Gooty-Madhugiri 400 kV D/C line along

with the associated bays is system strengthening scheme and it is not merely to serve

the distribution companies of Karnataka and whether the line could be utilized

effectively with the commissioning of Madhugiri-Bidadi line in the absence of

downstream system of Karnataka.

4. Subject to the above, the Commission reserved the order on the issue of

"maintainability".‟

SRPC Secretariat had furnished comments as directed by Hon‟ble CERC.

23.2.4 SRTS-II, PGCIL vide letter dated 24.11.2016 (Annexure-XXXIII) addressed to KPTCL

had informed that with the administrative support of Karnataka State Government, the

ROW issue of 400 kV Nelamangala-Hoody LILO at 400 kV Yelahanka Station was

resolved. It was requested that the 220 kV evacuation system of KPTCL at Yelahanka SS

may kindly be expedited so as to facilitate the evacuation power through the 220 kV

downstream systems.

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.

30th

TCC: SR-II informed that in the recent Meeting held on

18.02.2017 with Secretary, Power and Chief Secretary, GoK,

police protection was assured to carry out the works.


23.2.5 Status of downstream at Madhugiri and Yelahanka is given below:

23.3 Upcoming inter-regional transmission schemes

23.3.1 KSEBL vide letter dated 31.01.2017 (refer Annexure-XVIII) had proposed to review the

status of upcoming transmission systems. It was stated that early commissioning of 765

kV Wardha - Nizamabad line and Angul – Srikakulam lines with associated lines is

urgently required to meet the power requirement. However, commissioning of above lines

and enhancement of ATC has not materialized till date resulting in alarming situation.

23.3.2 Updated status is furnished below please:

S S.No. Transmission Element Remarks

a) 765 kV Wardha – Nizamabad-

Hyderabad D/C line

Original Schedule by May 2018.

PGCIL trying to complete by June

2017.

30th

TCC:

PGCIL had informed that by March 2017, Wardha - Nizamabad and

Dichipally – Dichipally (HTLS) lines would be completed. Nizamabad-

Maheshwaram (Hyderabad) section would be completed by June 2017.

TSTRANSCO confirmed that they would be bringing up the

downstream system in the same timeframe.

PGCIL stated that the Tariff for the above elements should be allowed

as and when the elements come up.

TCC recommended the same for the approval of SRPC.

31st SRPC :

SRPC agreed that Tariff for above elements would be allowed as and

when the elements come up.

Sl.

No

Name of

Transmission

Element

Exe.

Agency

Sch. CoD Expected

date

Remarks

Tumkur downstream

1 220 kV Tumkur –

Antharasana Halli

D/C

KPTCL Tenders for

the above

line had been

placed on

18.03.15 and

it would take

18 months

for

completion

30th

TCC

update :

March 2017

2 220 kV Tumkur

(400 kV) S/S – 220

kV Tumkur S/S

D/C

KPTCL 30th

TCC

update :

March 2017

Yelahanka downstream

1 220 kV Yelahanka

(400/220 kV) S/S-

220 kV Yelahanka

S/S D/C Cable – 5

kM

KPTCL (5.875 kM) 30th

TCC

update :

December

2017


b) WR-SR 6000 MW HVDC Bipole Link

[Raigarh (Chhatisgarh) - Pugalur-

Trichur (TN/KER)]

Nov’ 2019

30th

TCC:

PGCIL had informed that package for the terminal at both ends had been

awarded. Package for the line is expected to be awarded during March 2017.

c) 765 kV Angul - Srikakulam PS D/C

line

765 kV Angul-Srikakulam D/C:

COD from 01.02.2017

765 kV Srikakulam-Vemagiri

(PVTL) D/C: COD from

01.02.2017

1500 MVA ICT-I at Vemagiri:

COD from 01.02.2017

240 MVAR Bus Reactor I & II at

Vemagiri PS: COD from

01.02.2017.

LILO of 400 kV Gazuwaka-

Vijayawada S/C at Vemagiri PS:

COD from 01.02.2017.

80 MVAR Bus Reactor at Vemagiri

PS: COD from 01.02.2017.

240 MVAR Line Reactor at

Vemagiri and Srikakulam PS for

both circuits of Srikakulam PS –

Vemagiri PS 765 kV D/C line:

COD from 01.02.2017.

Other associated elements by

Jun’2017-Dec’ 2019

30th

TCC:

TCC noted the above.

d) Additional inter-Regional AC link for

import to Southern Region, i.e.,

Warora - Warangal - Hyderabad-

Kurnool 765 kV link

TBCB, PFCCL- BPC Schedule was 40 months from the

transfer of SPV (around mid-

2019).

Discussed in 36th

Meeting of

Empowered Committee scheduled

for 26.07.16

Hon‟ble CERC in its Order dated

29.09.2016 in respect of Petition

No 111/TL/2016 had granted

Transmission License to Warora-

Kurnool Transmission Limited

(WKTL).

29th

TCC:

M/s Essel Infra has been selected through TBCB. SPV was transferred on

06.07.2016 with a schedule of 40 months.


e) System strengthening within SR for

transmitting power beyond Vemagiri

TBCB- RECTPCL-BPC–Some

scope of work/ reactive

compensation modified.

The project has been awarded to

PGCIL under TBCB, and was

expected by April 2019.

30th

TCC:

All associated transmission system is scheduled to be completed by April

2019. The dispersal of power from Kadapa - Madhugiri needs to be

expedited/ensured.


23.3.4 Updated detailed status of upcoming inter regional scheme is furnished at Annexure-

XXXIV.

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

23.4.1 Common System Associated with NTPL / Costal Energen Private Ltd / Ind-Barath

Power Ltd, Tuticorin Area

Updated status of associated links is furnished below:

Transmission

Elements

Line

Lengt

h

(ckm)

Impleme

nting

Agency

Sch

COD

Ant

COD/

Act

COD

Constraints/

Remarks

765 kV D/C Tuticorin

PS - Salem PS line

(Dharmapuri) (initially

charged at 400 kV)

731 PGCIL Dec'14 COD from 13.11.2016

400 kV D/C Salem PS

– Salem line

120 PGCIL COD from 23.10.2016

765 kV S/C Salem PS

(Dharmapuri) -

Madhugiri P S line

(initially charged at

400 kV)

245 PGCIL Dec'14 March-

17 29

th TCC update:

Severe ROW

problems in

Karnataka. Critical.

Covered under

PRAGATI.

765/400 kV Salem PS

(initially charged at

400 kV)

PGCIL COD from 13.11.2016

400 kV D/C Coastal

Energen – Tuticorin

PS

54 Coastal

Energen

Ckt I charged on 29.10.2016

Ckt II charged on 27.10.2016


23.4.2 Transmission system associated with IPPs (IL&FS) of Nagapattinam/Cuddalore Area

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. Agency Sch

COD

Ant.

COD

Constraints/

Remarks

Nagapattinam PS-

Salem New

765 kV D/C line

406 Power grid

Nagapattina

m-

Madhugiri

Transmission

Company

Limited

(PNMTCL)

(A subsidiary

of PGCIL)

Mar‟

15 COD from 21.10.2016

Salem New –

Madhugiri 765

kV S/c line.

219 30th

TCC:

June

2017

Severe RoW issues

being faced in

Karnataka.

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

from IL&FS (2x600MW)

Following may please be noted in this regard:

It was noted that some stringing/ upgradation was pending within NLC Complex.

These works had been envisaged as a contingency evacuation for IL&FS.

SR-II, PGCIL had informed that they would be taking up work during shutdown of one

of the units at NLC TS-I Exp. There may be one day requirement of shutdown of both

the units at NLC TS-I Exp.

A Meeting was held regarding Transmission System Associated with IPPs

Naggipattnam/Cudalure Area package A held on 15.09.2016 in CEA. The minutes are

enclosed as Annexure-XXXV.

23.4.2.1 TCC deliberations

It was noted that Hon‟ble CERC in its order dated 07.02.2017 in respect of Petition

No.222/TT/2016, in respect of TANGEDCO issues had directed Chief (Engineering),

CERC to look into issues raised by TANGEDCO with reference to various applicable

regulations and submit a report within a month.

23.4.2.1 SRPC noted the above.

23.4.3 Evacuation of Power from HNPCL (1,040 MW) Power Plant (i) Updated status of associated links under APTRANSCO‟s scope is furnished below:

Transmission

Elements

Line

Length

(ckm)/M

VA cap.

Implementing

Agency

Target

Date

Target

date

completio

n

Constraints/

Remarks

Startup Power Line

from M/s. HNPCL

TPP to 400/220 kV

Kalpakka SS

7 APTRANSCO Commissi

oned on

07.02.14


400 kV TM D/C

Line from HNPCL

- Kamavarapukota

S/S (Lot-I, II &

III)

200 APTRANSCO Jul „15 30th

TCC:

June 17

Purchase Order

issued on

03.11.2015.

400 kV TM D/C

Line from

Kamavarapukota

S/S - Vemagiri 400

kV S/S

185 APTRANSCO 30th

TCC:

June 17

All the

foundations, tower

erections and

stringing works are

completed.

400 kV TM D/C

Line from

Kamavarapukota

S/S - 400 kV

Chinna Korukondi

S/S

179 APTRANSCO Sept.

„15 30

th TCC:

June 17

Test charged on

20.10.2016

Kamavarapukota

Substation

2x315

APTRANSCO Mar

„16 30

th TCC:

Mar 17

2 Nos. of 400 KV

Bay Extensions at

existing 400/220

KV Kalpaka S/S of

HNPCL

APTRANSCO Commissi

oned on

18.11.13

(ii) Updated status of associated links under TSTRANSCO‟s scope is furnished below:

Transmission

Elements

Line

Length

(ckm)/M

VA cap.

Implemen

ting

Agency

Target

Date

Target

date

completi

on

Constraints/

Remarks

400 kV TM D/C Line

from Chinna Korukondi

- 400 kV Suryapet S/S

170 TSTRAN

SCO

30th

TCC:

Charged

Suryapet S/S -

Nandiwanaparthi S/S

400 kV Quad D/C Line

240 TSTRAN

SCO

Mar‟15 Test

charged

on

28.07.16

400 kV Quad D/C Line

from Nandiwanaparthi

S/S - Shankarapally S/S

222 TSTRAN

SCO

Mar‟15 30th

TCC:

Charged

Suryapet Substation

400/230/132 & 2 Nos.

of 400 KV Bay

Extensions at 400 KV

Shankarapalli S/S

2x315

TSTRAN

SCO

30th

TCC:

ICT-I

Charged

ICT-II by

Mar 17


23.4.4 Transmission system of KPTCL for evacuation of power from Yermarus TPS (2x800

MW)

Updated status of associated links is furnished below:

Transmission elements Imp.

Agency

Line

Length

(ckm)/

MVA

cap.

Sch. COD Constraints/ Remarks

Bellary 400 kV PS near

„BTPS‟

JSWEL

(KPTCL

)

30th

TCC:

Mar 17

Completed

Gulbarga 400/220 kV

substation

KPTCL 2x500 Land acquired. Geo tech

survey work will be

awarded within a week.

Bill of Materials

prepared and estimate to

be prepared.

Yermarus TPS - Gulbarga

400 kV D/C line (QM)

KPTCL Detailed survey

completed.

Estimate is being

prepared.

400 kV SS at

Chikkanayakanahalli (C.N

Halli) near “Loop in Loop

Out” (LILO) point on the

Nelamangala – Talaguppa

400 kV lines to Hassan.

KPTCL 2x500

MVA

In 39th

SCPSPSR a

step down

SS with 2 x

500 MVA,

400/220 kV

ICTs was

agreed.

30th

TCC:

Land yet to be identified.

Alternate site at

Bindikere is under

consideration

LILO of both the circuits of


400 kV lines to the proposed

pooling station near CN

Halli.

KPTCL Linked with CN Hally

station

Termination of 400 kV D/C

line feeding 400/220 KV

station at Hassan from


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 285

(400 kV

MC Line

(5.138

Kms) and

400 kV

DC line

(137.355

Km)

Expected by

Aug‟17


totally for

a route

length of

142.493

Kms)

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 letter

no. 2504-06

dt 7.7.2015

29th

TCC update:

Part of the work from

Rampura-Jagalur 65 kM

had been awarded.

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

(KelaginaKanavi): (43.018

Kms)

KPTCL

Under

Executio

n by KECIL

By

Kalpatar

u PTL

377

86

Earlier

schedule:

22-Dec-16

30th

TCC

update:

Mar‟17

Earlier

schedule:

24-Apr-17

30th

TCC:

Completed

Bellary TPS – Bellary

Pooling Station 400 kV D/C

line with quad moose

conductor

KPTCL 10 In 39th

SCPSPSR it was

agreed to drop the

proposal.

Dropped

De-link 400 kV S/C line

running between RTPS-

BTPS-JSW-Guttur with

JSW Bus

KPTCL

Nov‟16 Agreed in 39th

SCPSPSR

400 kV M/C line from

JSW to BPS is under

progress, once this is

commissioned the link

between JSW & BPS will

be delinked.


23.4.5 Transmission System required for evacuation of power from Kudgi TPS (3x800 MW

in Phase-I) of NTPC Limited

Updated status is furnished below:

Following had been noted in earlier Meetings:

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

23.4.6 Transmission System for evacuation of power from Singareni Collieries Generating

Project (2 x 600 MW)

Following is the status update:

JSW TPS – Bellary Pooling

Station 400 kV D/C line

with quad moose conductor

KPTCL 30th

TCC:

Completed

Additional JSW TPS –

Bellary Pooling Station 400

kV D/C line with quad

moose conductor

Agreed in 39th

SCPSPSR

400 kV BTPS-Guttur D/C

line (QM)

Agreed in 39th

SCPSPSR

Transmission

Elements

Imp. Agency Schedul

ed CoD

Revised

Target

Date

Constraints/ Remarks

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 Trial operation completed on 23.09.2016

Tumkur - Bidadi 400

kV D/C (quad) Line

Trial operation completed on 24.08.2016

400/220 kV ICT 2 at

NTPC Kudgi

Switchyard

NTPC Charged on 06.09.2016

400 kV Bus Reactor -2 NTPC Charged on 21.09.2016

Transmission

elements

Length

(ckm/MVA

capacity)

Imp. Agency

Sche

duled

CoD

Target

date of

Completi

on

Constraints/

Remarks

1. 400 kV Singareni- Gajwel in two parts

a) 400 kV Jaipur

(Singareni) -

149.636

TSTRANSCO

Comp

leted

Charged

in Nov 15

Reactor also

commissioned


23.4.7 Transmission System for Rayalaseema TPS (600 MW)


23.5 Status of upcoming links having impact on S1-S2

Following is the updated status:

Sl.

No.

Transmission

Element Schedule

Expected

Commissio

ning Date

Remarks

1 400 kV

Somanahalli-

Dharmapuri PS

Jun‟15 June 2017 Severe RoW problems being faced in

Karnataka. Critical issues related

compensation not yet resolved.

Rangampet D/C

(Quad)

b) 400 kV

Rangampet- Gajwel

D/C (Quad)

174.852

TSTRANSCO

Comp

leted

Commissi

oned on

13.11.201

5

2. 400 kV Singareni-Nirmal in two parts

a) STPP, Jaipur –

Jagityal

142 TSTRANSCO 30th

TCC:

June‟ 17

Works Awarded

on Nov‟15.

b) Jagityal - Nirmal 148 TSTRANSCO Feb

17

30th

TCC:

June‟ 17

Works Awarded

on Oct‟15.

Transmission

elements

Length

(ckm/M

VA

capacity)

Imp. Agency

Schedule

d CoD

Target date

of

Completion

Constraints/

Remarks

RTPP (Stage - IV)

- Chittoor TM D/C

Line

(a). RTPP - Pedda

Jamgam Palli

(P.J.Palli)

(b). P.J. Palli-

Chittoor

(c) 220 kV

Muddanur(RTPP)-

Chinakampally 3

& 4

432

216

212

121

APTRANSCO

30th

TCC:

Mar‟17

30th

TCC:

Mar‟ 17

Commissioned

on 16.06.2016

400/220 kV,

Kalikiri S/S

2 x 315

MVA

APTRANSCO Sep‟17 30th

TCC:

2018-19

PO is placed in

Nov-15.

LILO of both

circuits of

Rayalseema IV-

Chittoor 400 kV

D/C line at Kalikiri

81

APTRANSCO


2

400 kV

Mangalore

(UPCL ) -

Kasargode-

Kozhikode

In the 39th

SCPSPSR, it was noted that

the process of implementation of 400

kV UPCL-Kasargode-Kozhikode line in

TBCB or regulated tariff in compressed

time schedule will be initiated as

applicable.

23.5.1 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. SR-II, PGCIL had informed that ROW issues for 400 kV Somanahalli -

Dharmapuri PS were yet to be resolved and it would take around two months to

complete the work once the ROW issues are resolved.


Shutdown was approved from 20.02.2017 to 20.03.2017 for Hosur-Somanahalli for

stringing of 400 kV Dharmapuri – Somanahalli line. However, this shutdown could

not be availed on account of ROW issues. Status of this line was also discussed in

the Meeting of Secretary, Power with Chief Secretary, GoK.

23.6 Critical Intra-regional transmission elements


Sl.

No. Transmission Element Expected CoD Remarks

1 765 kV Salem- Tumkur

By PGCIL (219 ckm)

Through TBCB

30th

TCC:

June 2017

30th

TCC:

Severe RoW being faced in

Karnataka.

2 400 kV Edamon-Kochi

(297 ckm)

30th

TCC:

Aug‟18

Being monitored under

PRAGATI


KSEBL had informed that the compensation would be paid from 01.03.2017 onwards.

SR-II, PGCIL had informed that a new contract would be awarded by March 2017 with

likely schedule of 18 months. Works would commence once compensation issues are

settled.


23.6.2 CMD, KSEBL confirmed that the compensation disbursement was planned from 1st March

2017 onwards and ROW of around 10 kms in phases would be handed over to PGCIL to

take up the works. With disbursement, the resistance was likely to come down. From 1st

April 2017, PGCIL was likely to commence works.

23.7 400 kV Trichur-Kozhikode line (Madakkathara-Areakode)

In the 39th

SCPSPSR it had been noted that Madakkathara-Areakode (Kozhikode) -

Kasaragode 400 kV D/C link may be taken up by KSEBL.


23.8 Requirement of additional ICT at 400 kV sub-station at Kozhikode

23.8.1 In the 39th

SCPSPSR, 1 x 500 MVA ICT at Areakode (Kozhikode) substation was agreed.

Subsequently, KSEBL vide letter dated 20.02.2016 had stated that PGCIL may take

necessary steps to provide additional ICT at 400 kV substation at Kozhikode temporarily

by using spare 315 MVA ICT till 500 MVA ICT is available. KSEBL had informed that

PGCIL had given an estimate of Rs.3 Crores for which approval was required. They

would intimate their decision within a week‟s time.

23.8.2 PGCIL had informed that 500 MVA Transformer approved in the Standing Committee

was under NIT with a schedule of one year.

23.8.3 Subsequently, KSEBL had approved PGCIL‟s proposal.


KSEBL had informed that 3rd

ICT of 315 MVA was likely to be commissioned by first

week of March 2017.

KPTCL had stated that KSEBL was continuing to draw 50-80 MW on Kadakola -

Kaniampetta line. Thus, upstream lines were getting over loaded and affecting essential

loads. KSEBL had stated that after commissioning of 3rd

ICT at Kozhikode, the loading

on this line would get reduced.


23.8.6 CMD, KSEBL stated that 3rd

ICT was expected by 5th

/6th

March 2017. This would provide

relief to northern parts of Kerala.

23.9 NLDC vide letter dated 20th

January 2017 (available in NLDC website) had highlighted

following transmission constraints in Operational Feedback for the quarter October-

December 2016 in respect of SR:

Transmission Line constraints:

400 kV Nellore Pooling Station -Nellore D/C line

400 kV Gooty-Nelamangala line & 400 kV Gooty- Somanahalli line. Loading on

these lines have been partially relieved after 400 kV Tumkur-Bidadi-Nelamangala

rearrangement.

400 kV Udumalpet- Palakkad D/C line

400 kV Hiriyur-Nelamangala D/C line

220 kV Bangalore Metro Network

Overloading of 220 kV Shoolagiri-Hosur(TN)-Yerrandahalli-Somanahalli S/C line

220 kV Sharavathy-Shimoga lines (3 nos) and 220 kV Sharavathy-Talaguppa (3 nos)

Constraints for Rayalaseema TPS Generation Evacuation – 30th

TCC: it was noted

that the constraints has been removed which was confirmed by SRLDC.

Transformation Capacity at 400/220 kV Kozhikode SS

Constraints in Chennai 230 kV System

Overloaded 220 kV Lines in Tamil Nadu

Constraints in 230 kV evacuation lines of MTPS and Kundah complex

Constraints in wind evacuation


ICT Constraints

400/220 kV 2 x 315 MVA ICTs at Gazuwaka – 30th

TCC: APTRANSCO expressed

concern on the overloading of the ICTs. SR-I, PGCIL informed that it could be

replaced with 2 x 500 MVA ICTs.

31st SRPC: It was noted that the requirement needs to be ratified in the Standing

Committee. SRPC approved in principle for 2x500 MVA ICTs in place of existing

ICTs. PGCIL was suggested to take up the issue in the Standing Committee for

ratification.

400/220 kV 2 x 315 MVA ICTs at Vemagiri

400/220 kV 3 x 500 MVA ICTs at Nelamangala

400/220 kV 3 x 500 MVA ICTs at Somanahalli

400/220 kV 3 x 500 MVA ICTs at Hoody

400/220 kV 2 x 315 MVA ICTs at Guttur

400/220 kV 2 x 315 MVA ICTs at Hiriyur

400/220 kV 2 x 315 MVA ICTs at Narendra

400/230 kV 2 x 315 MVA ICTs at Pugalur

400/230 kV 2 x 315 MVA ICTs at Trichy

400/230 kV 2 x 315MVA ICTs at Madurai

400/230 kV 2 x 315MVA ICTs at Thiruvalam

400/220 kV 2 x 315 MVA ICTs at Kozhikode

Respective entities were requested to kindly identify and implement short term and long term

measures to overcome these constraints in a time bound manner.

23.10 40th

Standing Committee on Power System Planning for Southern Region

CEA had issued Minutes of the 40th

SCPSPSR (MoM available at CEA website) held on

19th

November 2016.


24 UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH

TRANSMISSION NETWORK

24.1 Status update of the upcoming evacuation schemes in Southern Region for renewable as

given below is furnished at Annexure-XXXVI:

S.No. State Project Type of

Renewable

Project

Capacity

in MW

1 TS Gattu Solar Park Solar 500

2 AP N.P. Kunta Solar Park Project Solar 1500

3 AP Ghani/ Panyam Solar Project Solar 1000

4 AP Aspiri Wind Project Wind 1000

5 AP Suzlon Power Project Wind 300

6 AP Various, at Uravakonda area Wind 1361

7 AP Various, at Kondapuram area Wind 1109

8 AP Various, at Hindupur area Wind 680

9 AP Mailavaram dist. Kadapa Solar 1000

10 AP Talaricheruvu Dist Ananthpur Solar 500

11 KA Tumkur(Pavagada) Ultra Mega Solar

Park

Solar 2000


12 KA Gadag Wind Project Wind 80

13 KA Dhoni Wind Project Wind 587

14 KA Harti Wind Project Wind 244



17 KA Jagalur Wind Project Wind 177

18 KA Thalak Wind Project Wind 250

19 KA Thalak Solar Project Solar 200

20 KA Guttur Wind Project Wind 518

21 KA Davanagere and Chitradurga Wind 60

22 KA Davanagere and Chitradurga connected Wind

(proposed)

406

23 KA Athani Wind Wind 240

24 KA Chikkodi Wind 92

25 KA Chikkodi, Ghatprabha, Belgaum Wind 110

26 KA Chikkodi, Ghatprabha, Belgaum Wind 418

27 KA Atria Hydel Hydel 12

28 KA Cauvery Hydro Hydro 3

29 KA Pioneer Power Hydro 24.75

30 KA Pioneer Power Hydro 24.75

31 TN Mytrah Energy (India) Wind 300

32 TN Samimeru Wind farms Wind 48.5

33 TN SISL Green Infra Wind 48.5

34 TN Samiran Udaipur Wind farms Wind 48.5

35 TN Shivam Filaments Wind 48.5

36 TN R.S. India Global Energy Wind 480

37 TN Suzlon Power Infrastructure Wind 1000

38 TN Suzlon Power Infrastructure Wind 350

39 TN Vestas Wind Technology India Wind 150

40 TN Wind Projects at Samugarengapuram Wind 600

41 TN Kamuthi Solar Park Solar 1000

42 KER Kottathara Project Wind 80

43 KER Vettathur Project Wind 80

44 KER Kuyilimala Wind Project Wind 14.25

45 KER Kasargode Solar Project Solar 200

Data not present in draft NEP

Vol.2(Trans.)

46 AP Gamesa Renewable Pvt. Ltd.(Kurnool) Wind 350

47 AP Gamesa Renewable Pvt. Ltd.(Dhone) Wind 300

48 AP Galiveedu, Kadapa Solar 500

49 KA Ostro Dakshin Power Pvt. Ltd. Wind 300

50 KA Orange Ashok Wind Power Wind 250

51 KA Renew Wind Energy (TN) Pvt. Ltd.

(Koppal)

Wind 400

52 TN Inox Wind Infrastructure Services Ltd Wind 500

53 TN Vagarai Suzlon wind farms Wind 200

54 TN Regen Wind Farm (Vagarai) Wind 600 or 384

55 TN Renew Power Ventures Pvt. Ltd.(Karur) Wind 400

56 TN Orange Sironj Wind Power Pvt. Ltd. Wind 200


57 TN Ostro Alpha Wind Pvt. Ltd. Wind 400

58 TN BLP Energy Pvt. Ltd. Wind 250

59 TN Greenmint Power Pvt. Ltd. Wind 200

60 TN Gamesa Renewable Pvt. Ltd.

(Thoothukudi)

Wind 400

61 TN Sitac Kabini Renewables Pvt. Ltd. Wind 250

62 TN Gamesa Renewable Pvt. Ltd. (Karur) Wind 200

63 TN Green Infra Wind Energy Ltd. (Tirpur) Wind 250

64 TS Enerfra Projects (India) Pvt. Ltd. Wind 300

24.2 KSEBL vide letter dated 23.02.2017 (refer Annexure-XXXII) had informed that in the LTA

Meeting of SR constituents held on 21.02.2017 regarding connectivity of IPPs (Wind), it was

deliberated that CTU has to build additional substations for giving connectivity as per the

connectivity application of the Wind IPPs. None of the wind developers are willing to get

connected to STU, reported to be in view of the exemption of open access charges. It was

also noted that the requirement projected by the wind developers was with (N-1) security in

some cases. This would necessitate more number of bays in the 400 kV S/s, CEA had

suggested some of the links with one circuit instead of double circuit. CTU had pointed out

that some of the existing 400 kV S/s do not have expandability and proposed new substations

near the existing 400 kV S/s for providing connectivity to the grid. The scope of the wind

developer being limited to the 220 kV line from the generation point to the 400 kV S/s up to

the 220 kV bay, the balance of expenditure is impending on the LTA holders. In some of the

cases discussed, it was evident that injection of power is likely to cause transmission

constraints. To a query, CTU and CEA opined that the system strengthening can be

considered when such applicants apply for LTA. The probability of achieving the generation

now proposed by them is also to be considered. The approach of wind generation to leave the

STU connectivity to ISTS connectivity and passing over the additional expenditure to the

existing LTA holders was proposed to be deliberated in the SRPC forum.


MS, SRPC had informed that RE schemes are getting modified at times while some are

getting dropped also. It was suggested that the RE Projects/evacuation schemes may

kindly be reviewed and updated status be communicated. It was observed that timely

progress on these schemes needs to be communicated to SRPC Secretariat, being a

critical issue monitored by various bodies.

TCC had suggested that concerned entities to furnish the updated status to SRPC

secretariat in a time bound manner.



24.6 ED, SR-I, PGCIL stated that RE evacuation was planned and executed under critical/tough


conditions and compressed time lines based on committed dates by RE generators. For

example, at NP Kunta, NTPC had stated that project would come in three phases and works

were awarded for all the three phases matching with the time schedule given by them.

However, matching activities at NP Kunta (NTPC) end was not being observed and PGCIL

should not get penalized/affected in any manner on account of delay at generation end.

24.7 Transmission System associated for Tumkur Ultra Mega Solar Park (2000 MW)

Transmission

Elements

Line Length

(ckm)/

MVA/MVAr

Capacity

Implem

enting

Agency

Sch

COD

Ant

COD/

Act COD

Constraints/ Remarks

A. Transmission system for connectivity by September 2017

400/220 KV Tumkur

(Pavagada) Pooling

Station

1 x 500 MVA

Oct 18 PGCIL

trying to

commissi

on the

system

matching

with

generatio

n

LILO of 400kV Gooty

–Tumkur

(Vasantnarsapur) D/C

at Tumkur (Pavagada)

PS

5

PGCIL Oct 18 Award placed in

Jun‟16. Survey had

been completed.

220 kV Line Bays (8

nos) at 400/220 kV

Tumkur (Pavagada) PS

for solar

interconnection

Oct 18 8 No. of Line Bays

required

Bus Reactor at Tumkur

(Pavagada) pooling

Station

1 x 125

MVAR

Oct 18

B. Phase-I : Transmission system for LTA Tumkur Ultra Mega Solar Park (1000 MW) by

September 2017

Tumkur PS - Hiriyur

400 kV D/C line (as

part of

Tumkur(Pavagada)

Pooling Station -

Mysore line)

218

PGCIL Oct 18 PGCIL

trying to

commissi

on the

system

matching

with

generatio

n

For 400kV Tumkur –

Mysore line section

routed via Hiryur S/s.

Award placed in

Jun‟16.

LILO of 400kV Bellary

Pool – Tumkur


(Quad)(both

circuits)[KPTCL line]

at Tumkur (Pavagada)

Pooling station*

110

PGCIL Oct 18 *KPTCL would

complete Bellary

pooling station –

Tumkur

(Vasantnarsapur) line

D/C (Quad) by

December- 2016.

Award placed in

Jun‟16.


Augmentation of

400/220 KV Tumkur

(Pavagada) Pooling

Station

2 x 500 MVA

Oct 18 Award placed in

Apr‟16

C. Phase-II : Transmission system for LTA Tumkur Ultra Mega Solar Park (1000 MW) by

September 2018

Hiriyur–Mysore 400

kV D/C line

190

Oct 18 One ckt would be

connected with one ckt

of Tumkur-Hiriyur to

make Tumkur-Mysore

direct line

Fixed series Capacitor

(40%) on 400 kV

Tumkur (Pavagada) -

Tumkur


(Quad) line at Tumkur

(Pavagada) Pooling

Station end

Augmentation of

transformer at 400/220

kV Tumkur PS

2 x 500 MVA

2nd

Bus Reactor at

Tumkur (Pavgada) PS

1 x 125

MVAR

Third 400/220 kV

MVA transformer at

Tumkur

(Vasantnarsapur)

1 x 500 MVA

Switchable Line

Reactor(LR) at Mysore

end of Hiriyur-Mysore

D/C for each circuit

1 x 80

MVAR

D. Additional ATS for Tumkur(Pavagada), to match with the commissioning of Devanahalli

SS of KPTCL

400 kV Tumkur

(Pavagada) -

Devanahalli (KPTCL)

D/C (Quad) line with

some portion on multi

circuit towers

125 KPTCL would

complete establishment

of 400/220 kV

substation at

Devanahalli including

inter-linking 400 kV

and 220 kV lines

before Phase-II at Ultra

Mega Solar Power

Park.

24.7.1 In earlier Meetings, the following had been noted:

SR-II, PGCIL had informed that they were focusing on completing the Pavagada SS and

LILO of Gooty-Tumkur line at Pavagada SS. As per Investment Approval scheduled

date of LILO of Gooty-Tumkur at Pavagada and Pavagada SS was Oct 2018 but PGCIL

was expediting to advance the commissioning.


It was noted that Tumkur Ultra Mega Solar Park Phase-I (1,000 MW) was expected by

April 2017.


KPTCL had informed that 500 MW would be coming up by June 2017. Second module

of 500 MW was expected by September 2017. The project was scheduled to be

completed by September 2018.

PGCIL had informed that evacuation would be ensured matching with generation

modules coming up.


25 NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP

25.1 Krishnapatnam UMPP (6x660 MW)

25.1.1 Following had been noted in earlier Meetings of SRPC:

The matter is sub-judice in High Court of Delhi.

APTRANSCO & APGENCO had informed that APSPDCL was the lead procurer. Over

a period of time this project was non-starter and it was unlikely to start in future also.

Except land leveling no work had been undertaken. CAPL had made presentation to the

procurers for exit from the project. Hon‟ble High Court had posted the case on 22nd

April 2016 and project was being constantly monitored. Even in the last procurer‟s

Meeting, CAPL was suggested to come out with a reasonable proposal.

Progress of Krishnapatnam UMPP had been uploaded in MoP website with the

observation „The project was handed over to Reliance Power Ltd. on 29.01.2008. The

developer has stopped work at site, citing new regulation of pricing in Indonesia. Lead

Procurer namely Andhra Pradesh South Power Distribution Company (APSPDCL) has

issued termination notice to Coastal Andhra Power Ltd (CAPL). The case is subjudice

in division bench, Delhi High Court.‟


APTRANSCO had informed that in the last Procurers Meeting, lead procurer

(APSPDCL) had been suggested to obtain legal opinion on APTEL Order and ongoing

legal proceedings. APTRANSCO had requested consent of other procurers to seek legal

opinion.


25.2 Cheyyur UMPP (4,000MW)


CTU had informed that this project had been identified under „Plug and Play Mode‟ and

new bids would be called.

Progress of Cheyyur UMPP has been uploaded in MoP website with the observation „The

site at Cheyyur in Kanchipuram District in Tamil Nadu has been identified along with

captive port at Panaiyur village. Request for Qualification (RfQ) and Request for Proposal


(RfP) issued in 2013 were withdrawn. Fresh RfQ and RfP are to be issued after the

finalization of Standard Bidding Documents.‟

TANGEDCO had informed that land acquisition was over. In case the bidding process is

getting delayed they were willing to take the project by themselves.

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

and BHAVINI & UMPP is furnished below:

Station Unit

Installed

Capacity

MW

Scheduled date of

synchronizing /

commissioning

Remarks

NTPC

Kudgi TPS

Stage-I

I,II,

III

3 x 800=

2400 Unit-I Synchronized and

achieved full load on

25.12.2016.

CoD by April/May

17.

Unit-II

Synchronization by

Feb‟17. CoD by

Aug‟17

Unit–III Synchronization by

May 17. CoD by

Nov‟17

On a query, NTPC

confirmed that full DC

would be ensured and there

were no constraints.

Telangana STPP

Phase I

2 x 800 U-I CoD May 2020

U-2 CoD Nov 2020

Pudimadaka AP 4 x 1000 52 Months from Zero

Date

85% share to AP.

Zero date yet to be finalized.

AP requested NTPC to firm

up the zero date at the

earliest.

AP informed evacuation

system would be developed

by PGCIL

30th

TCC: NTPC informed that the domestic coal was yet to be tied up.

APTRANSCO informed that they would apply for LTA with CTU after the

coal linkage is firmed up.

NLC

New Thermal

Power Project

I 500 April 2018 CTU had informed that for

evacuation LILO of Neyveli -

Puducherry and 400 kV D/C to

Araliyur lines are planned. NLC

had applied for LTA of 340 MW

which could be managed with the

LILO of Neyveli – Puducherry.

Balance 600 MW would be

catered by 230 kV system of

TANTRANSCO. Araliyur S/S

II 500 April 2018


was being developed by

TANTRASCO and was expected

by June 2018

NPCIL

Kudankulam St-I II 1000 COD: By March

2017

Unit-II: First synchronized to

grid at 11:16 hrs of

29.08.2016. Scheduling

started from 14.10.2016.

BHAVINI

Kalpakkam

(PFBR)

I 500 Synchronization by

March 2017

COD by Sep 2017

UMPP

Krishnapatnam 3960

(6 x 660)

APEPDCL and PCKL had

taken steps with their legal

counsel to expedite the

hearing before Honorable

High Court of Delhi

Cheyyur 4000 New bids would be called

26 NEW PROJECTS OF STATE SECTOR & IPP

26.1 Updated status of new projects of State sector is furnished below:

Sl

No

Name of project Located

in

Capacity

in MW

Commissioning Schedule

/Remarks

1 Rayalaseema TPS ST-

IV

AP 1 x 600 Synchronization by June 2017

COD by Dec 2017

2 Dr. NTTPS,

Vijayawada

AP 1 x 800 2017-18

3 Krishnapatnam Stage II

(U3)

AP 1 x 800

4 Polaki AP 4000 (5 x

800 MW)

5 Bellary TPS U-3 KAR 1 x 700 Achieved full load on

01.03.2016. COD on 16.09.2016

6 Yermarus TPS KAR 2 x 800 Unit-I: FL achieved on

29.03.2016. Unit II: COD by

2016-17

7 Edlapur KAR 1 x 800

8 North Chennai Stage

III

TN 1 x 800 2019-20

9 North Chennai Stage

IV

TN 2 x 800 Beyond 2019-20

10 Ennore TPS Exp TN 1 x 660 2018

11 Ennore replacement TN 1 x 660 2018

12 Udangudi Stage I TN 2 x 660 2019-20

13 Uppur TPP (TBCB) TN 2 x 800 2019-20


14 Singareni Telangana 2 x 600 Unit I: CoD from 25.09.2016

Unit II: CoD from 02.12.2016

15 Manuguru PPP Telangana 4 x 270 U1 : 20.03.2017

U2: 20.05.2017

U3: 20.09.2017

U4:20.09.2017

16 Kakatiya TPP Stage III Telangana 1 x 800 2017-18

17 Kothagudem TPS

Phase VII

Telangana 1 x 800

18 Damaracherla

(Yadadri)

Telangana 2 x 600 +

4 x 800

2018-19

26.2 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 2 x 350 2017-18

Untied: 640 MW

2 East Coast Energy

Thermal

AP 2 x 660

2017-18

AP : 300 MW

3 Thermal Powertech

(TPCIL) Unit-III

AP 1 x 660

2017-18

4 SGPL (NCC)

Krishnapatnam

AP 2 x 660

Unit I : CoD from 17.11.2016

Unit II: Syn. by June 2017

AP: 500 MW (firmed up PPA to

be signed).

5 Godhna TPP, Janjir –

Champa Dist,

Chhattisgarh

For

KAR

2 x 800 2017-18

27 METHODOLOGY FOR CERTIFICATION OF INTRA-STATE TRANSMISSION

LINE

27.1 APTRANSCO vide letter dated 09.12.2016 (Annexure-XXXVII) had requested SRPC to

certify certain intra state lines so that the same could be considered for inclusion in POC

charges.

27.2 Clause 2.1.3 of Annexure –I CERC Third Amendment of Sharing of inter-State

Transmission Charges and Losses Regulations 2015 states as follows:

“Certification of non-ISTS lines carrying inter-State power, which were not approved by

the RPCs on the date of notification of the Central Electricity Regulatory Commission

(Sharing of Transmission Charges and Losses) Regulations, 2009, shall be done on the

basis of load flow studies. For this purpose, STU shall put up proposal to the respective

RPC Secretariat for approval. RPC Secretariat, in consultation with RLDC, using WebNet

Software would examine the proposal. The results of the load flow studies and

participation factor indicating flow of Inter State power on these lines shall be used to

compute the percentage of usage of these lines as inter State transmission. The software in

the considered scenario will give percentage of usage of these lines by home State and

other than home State. For testing the usage, tariff of similar ISTS line may be used. The


tariff of the line will also be allocated by software to the home State and other than home

State. Based on percentage usage of ISTS in base case, RPC will approve whether the

particular State line is being used as ISTS or not. Concerned STU will submit asset-wise

tariff. If asset wise tariff is not available, STU will file petition before the Commission for

approval of tariff of such lines. The tariff in respect of these lines shall be computed based

on Approved ARR and it shall be allocated to lines of different voltage levels and

configurations on the basis of methodology which is being done for ISTS lines.”

27.3 It was proposed to evolve a methodology for SRPC certification of intra state lines, carrying

power to other states, to be applicable to all the utilities, with consensus on the same.

Methodology prepared by SRPC is enclosed as Annexure-XXXVIII please.

27.4 This matter had been discussed in the 33rd

Meeting of Commercial Sub Committee held on

31st January 2017. After discussions, the Commercial Sub Committee had recommended the

methodology prepared by SRPC for approval. This methodology was put up for approval.


APTRANSCO had stated that the methodology had not been agreed by APTRANSCO in

Commercial Committee Meeting. SOR to 3rd

Amendment of Sharing Regulations

suggested that lines carrying 10 % interstate power could be considered to be included in

PoC computations.

TSTRANSCO had stated that there are no standards in place presently to decide on any

percentage.

TCC had concurred with the recommendations of Commercial Committee and placed the

same before SRPC for approval. It was agreed that 50% criteria would be reviewed later

after experience/feedback is available on the issue.


27.7 APTRANSCO stated that 50% criteria seem to be on the higher side and requested for a

review.

27.8 SRPC approved the recommendation of TCC. It was agreed that 50% criteria would be

reviewed later after experience/feedback is available on the issue.

28 EMERGENCY RESTORATION SYSTEM (ERS)

28.1 Requirement of ERS had been outlined in MoP letter dated 05.12.2014. CEA vide letter

dt.18.04.2016 had sought updated status on the ERS which was communicated to the States.

Status update is given below:

Transmission

Utility

Requirement

as per MoP

Existing Status/Remarks

APTRANSCO 3 Nos. ERS I – Placed at Nellore

ERS II – Placed at Vizag

ERS III – Submitted for approval for

PSDF funding


TSTRANSCO 1 No. To be retendered

KPTCL 2 No. 2 Nos.

KSEBL 1 No. Tenders to be floated

TANTRANSCO 2 Nos Under consideration

PED Nil

PGCIL 4 Nos. ( 2

Nos.

additional)

2 Nos (SR

I & SR II

was having

1 No. each)

Inspection completed-Would be

dispatched. Would be kept at Vizag

and Chennai. Expected by June 2017.

765 kV ERS (one each for SR-I and

SR-II) order would be placed in March

with a delivery schedule of 15 months.


CEA had informed that it has been decided that all Transmission Licensees (irrespective of

ownership) would maintain ERS as mandated in CEA Regulations. All ERS locations

should be available at RLDC website to ensure availability of ERS at particular location in

a timely manner. As per National Disaster Management System, one should be able to

deploy these ERS within two days. Even single line owners (TBCB) had been directed to

have ERS and there was an Order of CERC in this regard also.

Chairperson, SRPC had observed that Andhra Pradesh and Tamil Nadu need to have higher

number of ERS since their coastal belt was more prone to cyclones. During floods in

Chennai, PGCIL ERS had come in very handy.

TANTRANSCO had enquired about status of ERS S/S which had been approved earlier by

SRPC. Chairperson, SRPC had stated that as per Disaster Management plan, ERS SS may

also be required. This was basically required to run some essential services.

PGCIL had informed that that they had taken up tendering but there was no response, ERS

S/S has been dropped. The cost was exorbitantly high (around Rs 400 crores). ERS SS was

available up to 220 kV, but 400 kV ERS was too bulky and transportation was a problem.

They were still trying for a smaller transformer of 100/160 MVA with minimum breakers

instead of 315/500 MVA.

Chairperson, SRPC had suggested that PGCIL should go for smaller capacity transformers

to meet the objectives.


28.4 Chairman, TNEB stated that actual usage of ERS during the Vardha Cyclone period had

been assessed. Water borne/swamps were some areas where ERS was specially required,

however ERS technology was having limitations in such areas. In many places, restoration

of tower was faster than shifting to ERS.

28.5 APTRANSCO stated that ERS had helped them significantly during the Hud Hud cyclone.

28.6 It was noted that Ministry of Power had itself specified state wise ERS requirements. States

were suggested that they could consider taking up ERS procurement through PSDF

funding.

28.7 Chairperson, SRPC stated that one or two ERS S/S at lower capacity/voltage level as


deliberated in the earlier Meeting may be required.

28.8 ED, PGCIL stated that they were examining feasibility of ERS S/S technically/

commercially.

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

29.1 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:

Entity Bus Name Status Remarks

KPTCL

Hoody Reactor erected on

platform June 2017

Nelamangala Reactor erected on

platform June 2017

Entity Bus Name

Capacit

y in

MVAR

Approved

in Type Remarks

PGCIL

Vijayawada 2x125

20th

SRPC/

34th

SC Bus

1st : commissioned in

June 2016

2nd

: March 2017

Nagarjuna

Sagar 125

21st SRPC/

34th

SC Bus March 2017

Narendra 125 21

st SRPC/

34th

SC Bus

Commissioned on

23.01.2017

Hyderabad 125 21

st SRPC

PGCIL informed that it is

dropped

Gooty 125 22

nd SRPC

/ 36th

SC Bus March 2017

Hassan 125

36th

SC

Bus Commissioned on

18.12.2016

Khammam 125 Bus March 2017

Kudgi PG 125 Bus Commissioned on

30.12.2016

Trivandrum 125 Bus Commissioned on

24.01.2017

Nellore

(Existing) 125 Bus March 2017

Yelahanka 2x63 Bus Deferred as per 40

SCPSSR

Nellore PS

on NPS-

Gooty Line

2 x 63

(37th

SC) Line March 2017

Kudgi PG–

Tumkur

D/C at each

end

4 x 63 Line

Reactors commissioned

with line in December

2016

Cuddapah 50 to 125 39th

SC Yet to be awarded


Thiruvalam

765 kV 2 x 240 39

th SC

Commissioned with

Kurnool lines.

APTRANSCO

Vemagiri 125

36th

SC

Bus PO has been placed on

18.06.2016. Expected by

August 2017

Kurnool 125 Bus

Kalpakka 125 Bus

Chittoor 125 39th

SC To be taken up

Vijayawada 125 39th

SC

APTRANSCO/

APGENCO

VTPS Stage

IV 125 39

th SC

APGENCO informed

that reactor was coming

up with 800 MW unit.

APGENCO was

suggested to take up

independently

KPTCL Davangere 125 39

th SC KPTCL informed that

they are taking it up Talguppa 125 39th

SC

TANTRANSC

O

Almathy 125 39th

SC

Diversion order has been

issued from Kanarpetty

400 kV S/s.

Kayathar 125 39th

SC

Administrative Approval

accorded and being

taken up

TANTRANS

CO/

TANGEDCO

Mettur 125 39th

SC

Commissioning of

Palawadi 400 KV S/s is

expected in near future

and the MTPS –

Thiruvalam line will be

LILOed at Palvadi 400

kV S/s would be

completed in 2 months

and length of the line

will get reduced

considerably.

TSTRANSC

O

Mamidipalli 125

36th

SC

Bus Sanction of funding

from PSDF is received

for 5 Nos of 125 MVAR

reactors from MoP on

05.09.2016 and works

are in progress.

Expected to be

commissioned by June

2017.

Gajwel 125 Bus

Sankarapalli 125 Bus

Mehboob

Nagar 125 Bus

Malkaram 125

Bus

TSTRANSC

O/

TSGENCO

Srisailam

LB 125

39th

SC

Erection of GIS with

Bus reactor is not

suggestible due to

financial implications

and space constraint in

400 kV GIS of

SLBHES. Hence, the


erection of Bus reactors

shall be examined at

other end.

NPCIL Kaiga 2 x 125

Bus

KGS informed that

financial sanction is

received and works

would be completed in 2

years

UPCL Udupi 2 x 125

39th

SC

KPTCL informed that

the line is planned to be

LILOed at Drinking

water substation at

Yettinahole between

UPCL and Hassan.

Subsequently the studies

would be put up to

Standing Committee.

29.2 Concerned entities were requested to kindly expedite commissioning of reactors.

29.3 NGR bypass of reactors

29.3.1 Need for convertible line reactors which can be used as bus reactors had been highlighted

by SRLDC in various OCC Meetings. It had been noted that this aspect had not been

considered during planning/design stage itself and subsequently only, works were being

taken up. It had been suggested that provision to convert the line reactor as Bus reactor

could be made during the planning/designing stage itself to take care of variations during

peak/off peak, seasonal variations, RE integration etc.

29.3.2 SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed the issue for

discussion.

29.3.3 In SR, NGR bypass of 400 kV Nellore-Thiruvalam I & II, Thiruvalam-Kurnool I & II and

Kozhikode-Mysore I & II line reactors was scheduled for 2017-18. PGCIL had informed

that earlier as per norms 765 kV bypass arrangement was being carried out by breakers and

by isolators at 400 kV.


PGCIL informed that new Line Reactors were coming up with provision to be

convertible as Bus Reactors. For existing line reactors, NGR bypass works of Nellore-

Thiruvalam I & II, Thiruvalam-Kurnool I & II and Kozhikode-Mysore I & II would be

completed by August 2017.



29.4 Dynamic Compensation (Approved in 36th

SC)

Entity Bus Name

SC

MVA

GVA /

KA

Dynamic

Compensation

(STATCOM)

Mechanically

Switched

Compensation

(MVAR) Remarks

Reactor Capacitor

PGCIL

Hyderabad 18.4/

26.5

+ 200 MVAR 2x125 1x125 Tendering

Completed.

P.O. would

be placed

by June

2017 with

a schedule

of 24

months

Udumalpet 19.4/

28.0

+ 200 MVAR 2x125 1x125

Trichy 12.5/

18.0

+ 200 MVAR 2x125 1x125

29.4.1 PSDF– Installation of STATCOM by Power grid in Southern Region

The following had been noted in earlier Meeting:

SRPC had approved TCC recommendation of the proposal for funding through PSDF.

PGCIL could take up the project by itself in case proposal was not approved through

PSDF. However, all efforts should be made by PGCIL for PSDF funding.

KPTCL had suggested that one STATCOM could be shifted to any 400 kV SS of

Bengaluru. KPTCL was suggested to kindly take up the matter with the Standing

Committee on Power System Planning.

SRPC had suggested that a new study on STATCOM requirement could be carried out

and feedback provided to the Standing Committee. KPTCL‟s request could also be

considered in the Standing Committee.


PGCIL informed that 90% PSDF funding for STATCOM was envisaged.

NPC informed that the approval of SRPC has not been communicated by PGCIL to

PSDF Appraisal Committee. PGCIL was requested to take necessary action in this

regard.


29.5 Reactive Power Planning

29.5.1 Status of Capacitor installation in Transco/Discoms is given below:

Utility Reactive Power Planning Voltage

level

Remarks

APTRANSC

O

Kadapa: 86.4 MVAR

Vijayawada: 172.8 MVAR

Visakhapatnam: 158.4

MVAR

On 33 kV

side

50.4 MVAR commissioned



APSPDCL 72 MVAR 18 MVAR commissioned

APEPDCL 218 MVAR

TSNPDCL 123 x 2 MVAR 123 x 2 MVAR and 118 x 1


118 x 1 MVAR MVAR capacitors had been

commissioned.

TSSPDCL 221 x 2 MVAR 11 kV 221 x 2 MVAR commissioned.

KPTCL Bengaluru Tr. Zone:708.8

MVAR

12.1 kV No update

Bagalkot Tr. Zone :258.1

MVAR

12.1 kV Material supplied. Erection

completed/under progress.

Hassan Tr. Zone : 150.8

MVAR

Material supplied. Erection

completed/under progress. Due

to space constraints 2*2.9

MVAR Capacitor Bank at

Belur, diverted from Belur to

Javgal 110kV Substation

Mysore Tr. Zone :60.9

MVAR

1x2.9 MVAR at Davanur S/s

commissioned on 26.10.2016

and 2x2.9 MVAR at Kikkeri

commissioned on 26.10.2016

Gulbarga Tr. Zone :98.60

MVAR

No update

Tumkur Tr. Zone :281.3

MVAR

12.1 kV 40.6 MVAR commissioned.

34.8 MVAR cable laying,

termination and testing and

commissioning works

completed. EI approval

awaited. At Haluvagalu due to

space problem, 2 nos of

capacitor banks are diverted to

JG Halli & Hariyabbe MUSS.

KSEBL

360 MVAR

66 kV Have done reactive

compensation study 360

MVAR is planned. Works will

be started shortly.

11kV

TANGEDCO 34 x 2.4 MVAR 11 kV 8 x 2.4 MVAR installed.

Balance works are under

progress

35 x 2.4 MVAR 11 kV Additional – Administrative

approval accorded. Tender to

be floated

16 x 2.4 MVAR 22 kV 8 x 2.4 MVAR installed.

Balance works are under

progress

51 x 2.4 MVAR 22 kV Additional – Administrative

approval accorded. Tender to

be plotted.

13 x 24 MAVR 110 kV BOQ approved by Board.

Tender opened. Techno

Commercial evaluation under

progress.

822 MVAR capacitors at

Distribution level had

Balance 109 MVAR will be

commissioned before 31.03.2017.

However for further enhancement


been commissioned out of

931 MVAR capacitors

planned.

of Reactive Power, Capacitor bank

provisions have to be arranged by

Planning/Transmission wings.

29.5.2 PSDF – Funding of the schemes of the state utilities for installation of capacitors in

the state network at transmission / distribution network

29.5.2.1 MS, Appraisal Committee & ED, NLDC vide letter dated 22.06.2016 had referred to the

schemes of state utilities for installation of capacitors in the State Network at

transmission/distribution network for funding from PSDF. The matter was deliberated by

the Appraisal Committee during the Meeting held on 31.05.2016 wherein, it was decided

that assessment of capacitor requirement may be carried out at regional level by engaging

expert agency like CPRI. In the 30th

Meeting, SRPC had approved TCC recommendation

that a regional proposal for capacitors installation would be put up for PSDF funding.

The Study would be conducted by CPRI.

29.5.2.2 A Meeting in this regard was conducted on 29th

November 2016 (MoM available on

SRPC website), wherein, the following had been agreed:

„Each state would furnish the converged PSSE base case for the Low Voltage/High

Demand scenario for its control area. LGB, Tap positions and assumptions for the

base case would also be furnished. STU would prepare the base case in consultation

with the DISCOMs. These details would be positively furnished to SRPC/SRLDC by

15th

December 2016. After validation by SRLDC/SRPC the details would be

communicated to CPRI.‟

29.5.2.3 TN had furnished the details while the details from other states were awaited. Further

each state in the region would need to contribute Rs 5 lakhs for the study to be conducted

by CPRI.

29.5.2.4 TCC deliberations

MS, SRPC had stated that a comprehensive proposal (STU & Discom) was to be

furnished. This was getting delayed on account of various reasons. PSDF Appraisal

Committee had sought for a vetted regional proposal which would enable PSDF

funding. As agreed in the 30th

SRPC, CPRI was willing to take up the study. The matter

needs to be urgently expedited.

After deliberations the following was agreed:

All states agreed to positively furnish a comprehensive proposal of STU/DISCOMs

by 15th

March 2017.

All states agreed to make the payment of Rs. 5 Lakhs each due to CPRI for the study.

29.5.2.5 SRPC deliberations

29.5.2.6 NLDC was requested to consider individual proposals since comprehensive proposal was

taking some time due to delay due to various reasons.

29.5.2.7 NLDC stated that WRPC, ERPC and SRPC had been requested to submit a regional

proposal. The proposal from WRPC had been received recently.


29.5.2.8 Chairperson, SRPC stated that in the recent meeting with MoP, it was noted that they

were willing to approve proposals expeditiously. Proposals needed to be submitted

immediately to avail the funding.

29.5.2.9 SRPC noted that data would be submitted by 15th

March 2017 and payment to CPRI

would also be expedited.

30 OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS

30.1 In CCM Meetings, the following had been noted:

Puducherry vide letter dated 09.12.2016 informed that they had received Rs 54,366/- from

GUVNL and balance amount of Rs 48,355/- only to be paid by GUVNL.

Pending payments between WR& SR Constituents as on 10.01.2017 are as follows:

State Receivable from Payable to

Entity Rs Entity Rs

Andhra Pradesh

/ Telangana

MPPMCL 1,21,76,270

*

MPPMCL Nil

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

GUVNL 9,40,320

Kerala 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 GUVNL 48, 355 GUVNL Nil

* In the recent Meeting of SR-WR held on 09.11.2016 at WRPC, Mumbai, MPPMCL

informed that MPPMCL has to receive payment from APTRANSCO and the details

would be shared with APTRANSCO/SRPC Secretariat.

30.2 SRPC noted the above

30.3 Payable amount by PGCIL (WRTS / SRTS) to SR Constituents (as on 10.01.2017)

State/UT Amount

(Rs)

Received(Rs) Paid by SRTS II

on 01.04.2016

(Rs)

Balance to

receive (Rs)

Andhra Pradesh

& Telangana

47,05,447 3,69,848 10,16,847 33,18,752

Karnataka 49,79,733 3,91,407 10,76,120 35,12,206

Kerala 27,58,402 2,16,811 5,96,091 19,45,500

Tamil Nadu 47,21,994 3,71,149 10,20,423 33,30,422

Puducherry 9,24,035 72,629 1,99,684 6,51,722

Total 1,80,89,611 14,21,844 39,09,165 1,27,58,602

SR constituents had been requested to take up pending payment issue with concerned

WR utility directly, with a copy to SRPC / WRPC Secretariat.


SR-II PGCIL informed that an amount of Rs. 13,38,631 had been received from

Chhattisgarh and the amount would be dispersed.



31 NON-AVAILING OF OCC APPROVED SHUTDOWN

31.1 In OCC Meetings, it had been noted with concern that at times entities were not availing the

OCC approved shut downs as per schedule. Details of availed outages against OCC

approved shut downs (furnished by SRLDC) are given below:


SRPC suggested for better compliance in this regard.

31.3 Rescheduling / Deferment of OCC approved outages having impact on TTC/ATC

31.3.1 In the 127th

Meeting of OCC, it had been noted that Raichur Bus-1&2 shutdowns were

rescheduled to coordinate with shutdowns of transmission elements in WR (Aurangabad-

Sholapur and Wardha Bus-1). There was lack of correct and timely information which was

required for adequate power purchase requirements by states. The issue has also been taken

up WRPC. However, the following merit attention:

Shutdowns need to be planned more diligently well in advance and approved in WRPC

& SRPC (in future ERPC also) OCCs.

Change in date should not be encouraged and avoided. Any change in date affects the

power procurement of SR entities which is generally on a day ahead basis (it may

become to D-2 with the new IEGC amendment).

Entity Aug-16 Sep-16 Oct-16 Nov-16 Dec-16 Jan-17

Availed % with respect to the OCC approved outages

AP TRANSCO 47 66 63 62 29 34.5

KPTCL 40 8 0 20 33 66.7

KSEBL NIL NIL 100 0 0 50

TANTRANSCO 48 36 48 52 28 40.9

TSTRANSCO 43 80 44 73 29 42.9

PGCIL, SR1 80 55 100 33 38 47.6

PGCIL, SR2 52 33 65 23 25 57.1

NTPC 100 33 0 0 100 50

NLC 100 NIL 100 67 0 50

NTECL NIL NIL 100 NIL NIL NIL

NPCIL NIL NIL NIL NIL NIL NIL

KPCL NIL NIL NIL NIL 100 NIL

PNMTC NIL NIL NIL NIL NIL NIL

KTL NIL NIL NIL NIL NIL NIL

MEPL NIL NIL NIL NIL NIL NIL

TOTAL 55 47 56 48 41 46.9


Any deferments at the last minute leads to unnecessary costly power procurement and

also load generation balance issues.

Timing of revival of the units should be in line with the approved timings. Any delay

should be as far as possible avoided and the revised time schedule of the revival should

be informed well in advance (around 3-4 hrs).

31.3.2 KSEBL vide letter dated 21.01.2017 & 31.01.2017 (refer Annexure-IX & XVIII) had

expressed concern that the delay in completion of maintenance works on 28/29.12.2016

had resulted in a revenue loss of approximately Rs 160 lakhs to KSEBL. It was stated that

change in date of availing shut down and over stayal of shutdown works are matter of

concern. Also, non-availability of current information from SRLDC and NLDC control

rooms is also cause of worry.


KSEBL had expressed concern on rescheduling, lack of information to SRLDC/NLDC

by PGCIL and also delay in restoration during the above referred outages.

PGCIL had assured to take up the issue with other regions on adhering to schedule and

also timings.


31.4 Deferment of OCC approved outage

31.4.1 In the 125th

OCC Meeting, PGCIL had expressed concern that on several occasions, OCC

approved shutdowns were not being concurred in real time. Considerable effort and

money was frittered on account of such deferment etc.

31.4.2 After deliberations, it had been noted by OCC forum that entities should be allowed to

avail the OCC approved S/Ds on the approved dates itself. Considerable planning and

manpower is deployed to take up OCC approved S/Ds.


32 GRID STUDY COMMITTEE (TASK- 2) AUDIT PROGRESS DETAILS

32.1 As per MoP order dated 16.07.2014, M/s Tractebel Engineering (TE) has been appointed as

the 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).

32.2 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.

32.3 Under Task-2, 15 Stations from SR have been audited by the Consultant. The draft report on

Task-2 by the Consultant has been received. It may please be noted in this regard that based

on their audit, the Consultant has given certain general observations w.r.t. each station, and

the final set of recommendations will be provided by M/s Tractebel Engineering in their final

report on Task-2. A Meeting chaired by Member (GO&D), CEA is proposed to be held on

13th

February 2017 for finalizing this report.

32.4 Under GSC-Task 2 activities, Consultant, M/S Tractebel Engineering had conducted a five-

day training programme during 16-20 January, 2017 at SRPC Secretariat, Bengaluru on

protection system operation with specific focus on protection audit methodology and relay

setting calculations & coordination for SR-Constituents.


33 STATUS OF PHASE I AND PHASE II OF PROTECTION AUDIT

RECOMMENDATIONS

33.1 With reference to petitions filed by KSEB (88/MP/2016) and KPTCL (135/MP/2016) seeking

further time-extension for completing their respective Protection Audit Recommendations

(PAR), a review Meeting was convened by CERC Staff on 05th

October 2016 at SRPC

Secretariat, Bengaluru to ascertain status of implementation of Protection Audit

Recommendations (PAR) by various SR-Constituents. Based on inputs furnished by various

Constituents in the Meeting, detailed status along with probable timelines required for

completion of their respective PAR (Phase-I & Phase-II) had been worked out and furnished

to Hon‟ble CERC for taking a decision w.r.t. granting further time-extensions as sought by

various SR-Constituents.

33.2 Final Order of CERC disposing of above petitions was issued on 15.12.2016. In this Order,

Hon‟ble Commission, apart from granting last-chance time-extensions to various SR-

Constituents had also directed SRPC to monitor status of completion of PAR regularly in

PCSC Meetings and submit bi-monthly report to the Commission confirming the completion

of Phase-I and Phase-II of PAR of the Constituents of Southern Region.

33.3 Timelines given by Hon‟ble CERC, as per above Order dated 15.12.2016, to various

SR-Constituents for completion of their respective Phase-I and Phase-II works of Protection

Audit recommendations are given below:


33.4 Constituents were kindly requested to adhere strictly to time-lines given in the Order for

completing their respective pending PAR. IPPs for whom there are pending PAR [viz.,

Spectrum PGL, GMR Barge - Kakinada, Konaseema GPL, APGPCL Vijjeswaram Stage-I &

Stage-II), & LANCO-Kondapalli PL] were also requested to complete them.


34 SPARE ICT AND REACTOR PLACEMENT AND USAGE PROCEDURE

34.1 PGCIL had informed following status of spare ICTs and Reactors as agreed in earlier

Meetings:

Region Equipment Location

SR ICT Madurai (would be

reaching in Sep 2016) &

Hyderabad (was being

used at Sriperumbudur)

Reactor Vizag & Gooty (being

used at Somanhalli)

Status of Narendra reactor

35 IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION

35.1 Automatic Demand Management Schemes

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

have been provided by all constituents by 1st

January 2011. SRLDC & SRPC Secretariat

Sl.

No.

Constituent Date for completion

of Phase-I activities

Date for completion

of Phase-II activities

1 APGENCO (Hydel) 31.12.2017 31.12.2017

2 APGENCO (Thermal) 30.07.2017 ---

3 APTRANSCO 31.03.2017 ---

4 TSGENCO (Hydel) 31.03.2017 31.03.2017

5 TSGENCO (Thermal) 31.03.2017 31.03.2017

6 TSTRANSCO

31.03.2017 31.03.2017

7 KPCL --- 31 30.11.2016

8 KPTCL 31.05.2017 31.05.2017

9 TANGEDCO 31.12.2017 31.12.2017

10 TANTRANSCO 31.12.2017 31.12.2017

11 KSEB 30.11.2016 31.12.2017

12 NPCIL (MAPS) 31.01.2017 ---


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

requirements.


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 in 30th

TCC for subsequent enhancement to

49.9 Hz.

35.1.3 Number of incidents satisfying the existing logic and proposed logic is given in the Table.

It was recommended to migrate to IEGC limits of 49.9 Hz:

Month

Present settings Proposed settings as per IEGC

Frequency < 49.8 Hz for 15

Min. and OD = Min DSM

limit

Frequency < 49.9 Hz for 15

Min. and OD = Min DSM limit

No of instances

Meeting the

freq. limit

No of

instances

applicable

to states

No of

instances

Meeting

the freq.

limit

No of instances

applicable to states

AP KAR TN

Aug-16 NIL NIL 39 3 1 3

Sep-16 1 AP (1) 27 1 3 1

Oct-16 NIL NIL 20 1 0 5

Nov-16 NIL NIL 46 2 1 2

Dec-16 NIL NIL 56 9 0 10

Jan -17 NIL NIL 13 1 0 1


SRLDC & SRPC suggested that new set points at 49.9 Hz be adopted.

States pointed out that corrective action was already being taken by them as could be seen

that there were minimal incidents satisfying the proposed logic. Opportunity needs to

given to Operator to take corrective action rather than go for automatic load shedding and

existing set points were reasonable. Unnecessary interruptions to loads were not advisable

in the present scenario. In time of contingency, appropriate urgent action was being taken

by SLDCs.

TCC suggested that ADMS set points could be reviewed in the next Meeting of TCC.


35.2 UFR and df/dt reliefs

35.2.1 All States had implemented AUFR and df/dt schemes fully. SRPC vide letter dated

29.01.2016 had submitted status report duly certified by SRLDC and SRPC wrt

implementation of SCADA mapping of all constituents to Hon‟ble CERC in respect of

Order dated 27.11.2015 vide Petition No. 60/MP/2014. Details of recommended,


implemented, SCADA monitorable and actual relief being realized are shown in Table

below:

State AP TS KAR KER TN PUD SR

Recommended MW A 2782 2965 3539 1173 4176 103 14738

Implemented MW B 2782 2978 3559 1207 4544 116 15186

% B/A 100 100 101 103 109 113 103

SCADA

monitorable

MW C 1169 1898 3557 1184 3849 116 11773

% C/B 42 64 100 98 85 100 78

Average

Visible Relief

in November

2016

MW E 1179 1081 2575 1035 1979 81 7930

Wrt

monitorable %

E/C 101 46 72 87 51 70 65

Average

Visible Relief

in December

2016

MW F 1020 890 2363 1062 1717 76 5966

Wrt

monitorable %

F/C 87 38 66 90 45 66 49

Average

Visible Relief

in January

2017

MW

G

1108 1006 2640 1098 1661 76 7523

Wrt

monitorable %

G/C 95 43 74 93 43 66 62

35.2.2 In earlier Meeting, the following had been noted:

TANTRANSCO had informed that action had been taken for the provision of

MPLS/GPRS link and for suitable RTUs at 29 SS GCs connected for AUFR and df/dt

and the time line for completion was April 2017. Regarding monitoring of figures

connected in AUFR and df/dt, PO had been issued for procurement of transducers and

the data visibility would be improved by 31.01.2017.


discussion.


APTRANSCO had informed that 25 RTUs would be commissioned by May 2017 and

the visibility would get increased to 70 %. APTRANSCO was requested to initiate

action to improve visibility to 100 %.

TSTRANSCO had informed that 18 RTUs would be commissioned by March 2017

while balance 6 RTU‟s would be taken up later (Administrative Approval is for 24

RTUs). With 24 RTUs in position, the visibility would increase to 100 %.

TANTRANSCO had informed that 100% visibility would be ensured by June 2017.



35.2.5 In the 6th

Meeting of NPC held on 19.12. 2016 (MoM dated 12.01.2017 available on

CEA‟s website), issue of ensuring proper functioning of UFR and df/dt relays had been

deliberated and following was noted:

„After deliberations, it was decided that all RPCs Secretariat would furnish to NPC

Secretariat the procedure being followed by them to ensure healthiness of UFR & df/dt

relays. RPC Secretariat shall carry out periodic inspection, in line with the provisions

of IEGC.‟

35.2.6 Subsequently, SRPC Secretariat vide letter dated 16.01.2017 (Annexure-XXXIX) had

requested constituents to furnish details as sought by NPC. TSTRANSCO/

APTRANSCO/KSEBL/TANTRANSCO had furnished the details in this regard.


KPTCL was requested to kindly communicate the details.

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

35.3.1 RGMO response is being analyzed in Meetings of OCC. SLDCs were to analyze RGMO

instances posted by SRLDC for the generators in their control area and initiate suitable

action as per Order in respect of 84/MP/2015. Inadequate Response was to be taken up

with SERC (Petition No.302/MP/2013).

35.3.2 Performance of RGMO is being analyzed in the OCC forum. Summary for 5th

October

2016 instance is given in the Table below:

State

Hydro Thermal TOTAL

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

AP -8.7 -6.9 79% -180.5 -107.7 60% -189.2 -114.7 61%

TG -13.4 -14.0 104% -75.0 -43.1 57% -88.4 -57.1 65%

KAR -11.0 0.3 -2% -159.1 -8.5 5% -170.1 -8.3 5%

KER -14.1 -4.9 35% 0.0 0.0 -14.1 -4.9 35%

TN -2.3 0.7 -29% -133.9 -15.2 11% -136.2 -14.6 11%

CGS 0.0 0.0 -510.1 -92.2 18% -510.1 -92.2 18%

SR -49.6 -24.9 50% -1058.5 -266.8 25% -1108.0 -291.7 26%

35.3.3 SRLDC vide letters dated 18.10.2016 and 12.01.2017 (Annexure-XL) had furnished a

summary of RGMO performance of generating stations of SR during Q-2 (July –

September 2016) and Q-3 (October-December 2016) to Hon‟ble CERC.

35.3.4 Extension of RGMO status point to SRLDC/SLDC, is also being deliberated in the

Meetings of OCC and the concerned entities are kindly requested to complete the pending

works.

35.3.5 SRPC Secretariat vide letter dated 07.09.2016 & 02.02.2017 (Annexure-XLI) had taken


up issue of scheduling the units with NLDC. It was not understood whether all other

RLDCs were adopting the same scheduling practice for ISGS units for ensuring adequate

RGMO response. KSEBL vide letter dated 31.01.2017 (refer Annexure-XVIII) had

raised the issue of restricting the schedule of ISGS for RGMO performance. It has been

stated that SRLDC has not provided DC adopted by them for scheduling against actual

DC given by the generators. This has resulted in higher availability as per REA, whereas

such capacity is not available to the constituents. The Regional Energy Accounts from

January have been proposed to be revised using actual capacity made available to the

constituents.

35.3.6 NLDC vide letter dated 10.10.2016 (Annexure-XLII) had furnished a report on frequency

response characteristics (FRCs) region-wise and all India wise since 1st January 2015 to

2nd

September 2016. It is stated that duration of time when frequency remained within the

IEGC band is continuously improving as evident in average frequency profile curves.

Southern Region is exhibiting a better FRC than other regions. Ancillary Services had

been implemented w.e.f 12th

April 2016 leading to better tertiary control for frequency.

Frequency Variation Index (FVI) had shown continuous improvement and on 21.07.2016

best FVI of 0.024 was recorded. Average frequency on many days had been 50.0 Hz with

a standard deviation of 0.05 Hz. Though considerable efforts had been taken in this

direction, yet a lot of scope is left for improvement. On day to day basis, the sharp

frequency excursions at hourly boundary (significantly observed at 1300 and 1800 hours)

were also a cause of concern. Frequency plot of a typical day shows wide excursions to

50.20 Hz and above. These excursions had in many cases led to tripping of lines on

overvoltage creating insecure conditions. For further ramping up this exercise of

frequency smoothening, primary and secondary frequency controls are also necessary. As

per CERC order Date 13.10.2015, all generating stations that are regional entities must

plan to operationalize AGC along with reliable telemetry and communication and

communication by 01.04.2017. Efforts are already on in this direction so that secondary

control is available. Primary response through governor action is already expected to be

provided by generating units as per sections 5.2(f) to 5.2(i) of the IEGC. However, desired

response from generators was not received. It had been requested by NLDC that primary

response may kindly be ensured through governor response from generators in interest of

grid security and better frequency profile.


MS, SRPC had informed the following:


Hon‟ble CERC in its order in respect of Petition No. 383/MP/2014 (date of Order

15.02.2017) had mandated that FRC was to be monitored. Whenever any RGMO

incident is posted, the FRC should also get posted.

Hon‟ble CERC in its order in respect of Petition No. 65/MP/2014 had mandated

NTPC Ramagundam Units-1, 2 & 3 to go for Retrofit or adopt FGMO with MI.

TCC had suggested that generators take necessary steps to ensure desired Primary

Response. SLDCs need to monitor the performance of the generators and compute FRC

in its Control area. Pending status points (automatic) also need to be extended to

SLDC/SRLDC.

Regarding schedule restriction (for RGMO), SRLDC had stated that as per directive of

Hon‟ble CERC, they are restricting schedules and the Procedure has been well

deliberated in the forum.

On a query about whether the same Procedure for restricting the schedule was

implemented in other regions also, NLDC had informed that the Procedure had been

implemented in SR and they were endeavoring to implement in all the regions.

Constituent states had pointed out that they were losing on the fixed charges and

additional energy charges since more than one year.

After deliberations, TCC had recommended that the Procedure of restricting the

schedule for RGMO compliance by SRLDC should be kept in abeyance since SR

constituents were at a disadvantageous position compared to other regions.

RGMO/FGMO with MI response was mandatory for all the applicable generators in all

the regions. NLDC was suggested the follow a common procedure for all regions in the

country.


35.3.9 SRLDC informed that all RLDCs/NLDC were taking up the issue of restricting schedule

for RGMO compliance in all regions. No decision could be taken against CERC Order.

Scheduling was being restricted to normative and the margin beyond 100 % was being

ensured for primary response.

35.3.10 SRPC noted the TCC recommendation (except NLDC/SRLDC). SRPC felt that there need

for harmonization of such requirements like RGMO, for all applicable units in all the

regions.

35.3.11 SRLDC/NLDC informed that aspect of restricting the schedule for RGMO compliance was

covered in the proposed IEGC amendment.

35.3.12 NLDC informed that a petition for primary response in the interest of grid security had

been filed before Hon‟ble CERC.

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

35.4.1 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 respect of 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 was yet to be developed by all

utilities. The forecast was required for RRAS and Renewable Framework also.

35.4.2 The following had been noted in earlier Meetings:

TANTRANSCO had informed that forecast of NIWE and Wind Developers was having

a difference of 600 - 700 MW (equivalent to 3 thermal units). Demand estimation was

quite accurate and they were in the process of procuring the software and they would be

fully equipped before next summer.

CEA had informed that MoP was willing to give the task of load forecasting to CEA. In

this model, load forecasting data and weather inputs would be communicated to CEA

and CEA would furnish the forecast to the states.

It was agreed that a small group would be formed at SRLDC, and demand forecast

exercise would be undertaken for individual states in coordination with SLDCs. SRLDC

was entering into MoU with IMD and weather data would be integrated.

Parallely, all state entities agreed that CEA could carry out state-specific forecasting.

SLDC would submit necessary data to CEA. This would not involve any financial

commitment for the states.

35.4.3 Subsequently, CEA had informed that a Meeting in this regard was held in Oct 2016 and

consent of SR states was obtained. DFID UK collaboration was being implemented by

KPMG with CEA and was likely to begin in January 2017. Telangana State has been

selected for Pilot project in load forecasting and short term power procurement

optimization program. For this, active highest level of support of Telangana Power utilities

and its SLDC would be required and DFID/KPMG team would visit Hyderabad. This

project involves development of software tools and at a later stage, project implementation

for other states would be taken up by CEA.


35.5 Sudden Change in Demand/Frequency Excursion

35.5.1 In earlier Meetings, violation of Clause 5.2 (j) of the IEGC Regulations had 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 is 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.

35.5.2 Constituents had been requested to ensure necessary compliance.



35.6 Arranging of interruptible loads in four groups

35.6.1 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.

35.6.2 Existing schemes were not Meeting Regulatory requirement fully and further action was

required in this regard. Constituents had been requested to ensure necessary compliance.


35.7 PSS Tuning

35.7.1 4th

Meeting of PSS tuning was held on 13th

January 2017 and MoM is available at SRPC

website. PSS Study group also analyzed the Step Response Test Reports for the generators

which had furnished the reports and recommendations had been finalized. It is kindly

requested that necessary action may kindly be taken as finalized in the 4th

Meeting of PSS.

35.7.2 SRT of following units had been analyzed in the 3rd

and 4th

Meetings of PSS and necessary

action had to be taken as per Recommendations:

Entity Generating Stations/Units

APGENCO Rayalaseema TPS U1 to U5; VTPS U1 to U4 & U7; SDSPP U1&U2;

Srisailam RB HEP U1 to U7

AP IPP

TSGENCO Nagarjunasagar HEP U2 to U8

KPCL Raichur TPS U1,2,3,5,6,7& 8; BTPS U1 to U3; Varahi UGPH HEP

U1,2 & 4; Nagjheri HEP U1,2,4 & 5; Sharavathy HEP U3,5,7,9 & 10

KAR IPPs UPCL U1 & U2; JSWEL U2 & U3

KSEBL

TANGEDCO MTPS St-I U1 to U4; NCTPS St-1 U2 & U3; Tuticorin TPS U4 & U5

(to be analyzed)

TN IPPs

CGS NTPC- Ramagundam U7; NTPC-Simhadri U1 to U4; NTPC-Talcher

STPS St-II U 3 to U6; NTECL-Vallur TPS U1 – U3; NLC-Neyveli

TPS II U4 to U7; NPCIL-KKNPP U1

ISTS connected IPPs TPCIL U1; Coastal Energen U2; IL & FS U1 &U2

For the following Units, PSS was to be tuned and SRT to be carried out:

Entity Generating Stations/Units

APGENCO VTPS U5 & U6; Lower Sileru HEP U2 to U4

AP IPPs HNPCL

TSGENCO Kothagudem TPS U7 & U8, Nagarjunasagar HEP U1, Srisailam LB HEP U1

to U6, Sinagareni Collieries U1 & U2


KPCL Raichur TPS U4; Yeramarus TPP; Varahi UGPH HEP U3; Nagjheri HEP U3

& U6; Sharavathy HEP U1,2,4,6 & 8

KAR IPPs JSWEL U1 & U4

KSEBL Idukki HEP U1 to U6

TANGEDCO NCTPS St-1 U1(14.702013); NCTPS St-II U1 & U2; Tuticorin TPS U1 to

U3; Mettur St-II TPS U1; Kadamparai HEP U1 to U4

TN IPPs STCMS

CGS NTPC-Ramagundam U1 to U6; NTPC-Kudgi; Neyveli TPS I U7 to U9; NLC-

Neyveli TPS I Exp. U1 & U2 (SRT report not submitted); NLC-Neyveli TPS

II U1 to U3; NLC-Neyveli TPS II Exp U1 & U2; (NLC & TN JV)NTPL U1

& U2; NPCIL- KGS U1 to U4; NPCIL-MAPS U1 & U2; NPCIL-KKNPP U2

ISTS

connected

IPPs

Simhapuri Energy Ltd (SEL) U1 to U4; MEPL U1 & U2; TPCIL U2; Coastal

Energen U1; Lanco Stage II & III; SGPL-Nellore

35.7.3 In the 6th


website), it had been decided that a small group comprising of representative of Protection

Sub- Committee of respective RPCs and NLDC, NTPC would be formed to finalize a

common procedure.

35.7.4 SRPC noted the above and suggested that generators take necessary steps as finalized in the

PSS Meetings.

35.8 Scheduling of Simhadri STPS Stage-I by SRLDC

35.8.1 APTRANSCO had filed a Petition before Hon‟ble CERC in this regard and the petition was

admitted on 7th

January 2016.

35.8.2 Hon‟ble CERC had reserved Order in the matter in respect of Petition No.291/MP/2015.

35.9 Instantaneous Scheme for Sudden Withdrawal of Wind

35.9.1 TANTRANSCO had implemented the SPS for sudden withdrawal of Wind generation at

Udumalpet and Kayathar area and the same was in operation with effect from 27.04.2016.

35.9.2 In the Special / OCC Meetings, SRLDC had opined that the scheme was required to be

extended to other stations and other states as higher capacity ( > 500 MW wind and solar

projects were coming up.

35.9.3 Constituents were suggested to study and discuss the same in OCC.

35.10 Energy Generation data Management from Renewable Energy Sources

Monthly generation data in respect of renewal energy sources is to be submitted to CEA

with a copy to SRPC.



35.11 Treatment of Bilateral short term and collective transaction in case of grid

disturbances

In the 6th


website), after deliberations, NPC had recommended for the accounting methodology to be

submitted to Hon‟ble CERC.

35.11.1 SRPC noted the above

35.12 Power swing blocking (PSB) setting in Distance relays

In the 5th

Meeting of NPC held on 08.04.2016, 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.

35.12.1 SRPC noted the above

35.13 Other Issues requiring kind attention of TCC / SRPC

Following issues which are being followed up in the Meetings of Sub-Committees of

SRPC also merited kind attention:

220 kV Narketpalli-Chilakallu Circuit I (inter-state line between AP and TS) was

LILOed at Suryapet at TSTRANSCO without exchanging code from SRLDC. 230 kV

MAPS –Arni line was LILOed at Echur SS by TANTRANSCO on 08.08.2016 without

prior concurrence from SRLDC. Any reconfiguration on inter-state lines and lines

emanating from regional entities needs to be carried out only after approval from

SRLDC keeping in view the operational / commercial aspects involved.

TANTRANSCO to complete insulator replacement with polymer for Vallur-NCTPS

lines.

NTECL and PGCIL to coordinate and complete the insulator replacement for gantry

tower towards line at NTECL.

TSGENCO had communicated that after Meeting water requirement in the Tail Pond

project, OEM M/s.Hitachi would be taking up testing and commissioning of units for

Pump mode operation at Nagarjunasagar.

Nagarjunasagar Unit-4 was drawing more power (12 MW) due to uneven shutter gap of

guide vanes and water leakage through guide vanes. For Unit-6, air depression needs to

be carried out frequently. TSGENCO had informed that these would be rectified in next

overhaul.

TSGENCO had informed that in respect of condenser mode of operation for Srisailam

LB, it takes around 3-4 hrs to put all the units in condenser mode. TSGENCO had been

requested to revert back on technical feasibility to reduce this time.


N-1 violation of Nelamangala, Vemagiri, Hoodi, Somanahalli, Madurai, Narendra,

Nunna, Kalvindapattu, Ramagundam, Pugalur, Kozhikode, Gazuwaka and Trichy ICTs

had been highlighted in the OCC Meetings.

High loading of Kolar-Hosur and Udumalpet-Palakkad line had been highlighted in the

OCC Meetings.

Chittoor ICT was under prolonged outage and APTRANSCO to take corrective action.

SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed the A/R issues

for discussion.

A/R had been commissioned for Ambewadi-Ponda by KPTCL and enabling was

pending due to non-approval from Goa end. Ambewadi-Xeldam being operated in

radial mode but the provision for A/R to be ensured.

A/R for Nagjheri lines to be completed by KPTCL/KPCL.

A/R to be made available for Munirabad-Lingapur I&II and Munirabad-Kalyani by

KPTCL.

A/R to be made available for Warangal-Nagaram I&II, Warangal-Durshed and

Warangal-Bommakal by TSTRANSCO.

NTECL had under injected wrt the dispatch schedule during the period 31.12.2016 to

02.01.2017. The issue was deliberated in the 127th

OCCM.

Power grid Vizag Transmission Limited (PVTL) vide letter dated 27.12.2016

(Annexure-XLIII) had informed that they had declared COD of the Srikakulam-

Vemagiri 765 D/C Transmission Line. However, it was not considered for computation

of PoC charges was not considered by Validation Committee since the terminal

equipment was not ready and the subject system was not able to be used. Date of COD

of Vemagiri-Srikakulam 765 D/C line shall be intimated when the same is ready for use.

SGPL vide letter dated 23.12.2016 (Annexure-XLIV) had requested for enhancing the

net exportable capacity of SGPL units to 620 MW instead of 617 MW. The same would

be aligned with their connectivity grant by CTU of 1240 MW for two units. 620 MW

had been demonstrated during the trial run and was supported by the trial run data

submitted to SRLDC. The matter was under consideration of SRLDC.

SRPC Secretariat vide letter dated 24.11.2016 (Annexure-XLV) addressed to CTU had

sought certain clarifications regarding LTA operationalization in respect of M/s MEPL

whereas, LTA of 491 MW was granted to M/s SEL. CTUs reply in this regard is at

Annexure-XLVI. MEPL had filed Petition No. 312/MP/2015 which was listed for

08.01.2017.

6th set of Pollution measurement in SR were to be completed by 25.09.2016.

PGCIL and NTPC had filed a Petition No.42/RP/2016 and No.44/RP/2016 for review of

the Order dated 27.6.2016 in Petition No. 236/MP/2015 in respect of KTL Transmission

Lines. The Petition was heard on 19.01.2017 and has been listed for hearing on

28.02.2017.


KTL had filed Petition (248/MP/2016) with IA No. 64/2016 before Hon‟ble CERC in

the matter of „Petition for set-aside the letter dated 5.12.2016 issued by Bangalore

Electricity Supply Company Limited (BESCOM).‟ In the ROP dated 03.01.2017

following was directed :

„4. As regards the prayer in the IA, the Commission directed the petitioner to give a

bank guarantee of Rs. 4.3 crore by 9.1.2017 in favour of BESCOM (or the amount as

may be calculated as liquidated damages by BESCOM for the delay) for a period of

six months. The Commission directed BESCOM not to encash the bank guarantee

without seeking permission of the Commission. Subject to the above, the Commission

directed BESCOM not to take any coercive action against the petitioner in terms of its

letter dated 5.12.2016. Accordingly, IA was disposed of……….

The petition shall be listed for hearing on 9.2.2017.‟

The petition was heard on 09.02.2017 and was listed for 23.03.2017

NTPC had filed Petition (51/RP/2016) before Hon‟ble CERC in the matter of „Review of

Commission‟s order dated 29.7.2016 in Petition No. 201/TT/2015 in the matter of

approval of transmission tariff for 4 nos. 400 kV Line bays at Narendra (New) for Kudgi

TPS-Narendra (New) 400 kV 2XD/C Quad lines, 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 Region for 2014-19 tariff period

under Regulation-86 of CERC (Conduct of Business) Regulations, 1999 and CERC

(Terms and Condition of Tariff) Regulations, 2014‟. Hon‟ble CERC had admitted the

Petition and was listed for 06.12.2016 and had stated

„7. The staff of the Commission is directed to provide a copy of the instant review

petition to CEA and request CEA to give its comments on the NTPC‟s contention that

the Kudgi-Narendra (new) line can be utilized for drawl by Karnataka through ICTs

by 25.11.2016.‟

The petition was heard on 24.01.2016 and hearing on the matter was closed.

CEPL had filed Petition (246/MP/2016) in the matter of „Petition seeking deferment of

Long Term Open Access and relinquishment of part allocation of Long Term Open

Access under the Bulk Power Transmission Agreement dated 24.02.2010 under

Regulation 18 read with 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‟. The Petition was

admitted and was heard on 17.01.2017and is now listed for 28.02.2017.

TPCIL had filed Petition (240/MP/2016) in the matter of „Petition for seeking

declaration that no relinquishment charges are payable for termination of the Medium-

term Open Access, dated 6.10.2015, granted to the petitioner by Power Grid

Corporation of India Limited‟. The Petition was admitted and was heard on 17.01.2017

& 24.01.2017 and is now listed for 10.03.2017.

In the 125th

OCCM, NLC had informed that the construction works of the NNTPP are in

advanced stage and startup power of about 32.5 MW is required for trial operation of all

major equipments of the plant from February 2017.Connectivity of the plant with 400kV


system was granted by PGCIL vide intimation No.C/SEF/TA/C/S/11/17(R1) dt 18-11-

2013. Signing of Connection Agreement is in progress. The commissioning of the LILO

of 400 KV TPS-II – Pondicherry S/C Line at NNTPP Switchyard through which

connectivity is granted is scheduled to be completed on 31.03.2018 by PGCIL. In the

35th

Meeting of Standing Committee held on 04th

January 2013, as System

Strengthening, it was agreed for LILO of both circuits of 230 KV Neyveli TS-I –

Neyveli TS-II D/C line at NNTPS switchyard by NLC. These lines are owned by NLC

India Limited. Considering startup power requirement from February 2017, it is

proposed to avail startup power under DSM basis through the LILO of 230 KV lines

from TPS-II ISTS Switchyard and SEMs will be installed at all the locations for

computation of startup power drawn by NNTPP.

PGCIL vide their letter dated 01st August 2016 had informed works of Extensions of

230 kV Main and Transfer Buses in TANTRANSCO Switchyard at Checkanoorani 230

kV Station (Madurai SS) under SRSS-XXIII and Alunder 230 kV Station (Trichy SS)

under SRSS-XX are yet to be taken up by TANTRANSCO. PGCIL is expected to

commission ICT-3 at Madurai by September 2016 and at Trichy by December 2016.

TANTRANSCO had been requested to kindly expedite the aforesaid works. CTU had

stated that the issue of coordination and downstream network not being ready would

come into picture and charges would be required to borne as per Hon‟ble CERC‟s

Order. TNEB had assured of necessary action at their end. Subsequently, it was noted

that Madurai ICT was declared on COD from 31.12.2016.

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.

SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed to discuss

status review of System Protection using Optimization Technique– 30th

TCC: SRLDC

informed that they were planning a visit to Kolar along-with ABB Engineer with

participation and inputs from PGCIL Engineers. It was noted that the SPOT was only

in preliminary stage and SRLDC could bring the issue when a concrete technically

viable proposal is firmed up.

SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed to discuss

review of operation of Inter Regional and Intra Regional Links like Upper-Sileru-

Balimela etc - 30th

TCC: It was noted that the NLDC & other RLDCs could coordinate

to make these Inter Regional line operational. Other Intra-Regional lines need

concurrence of SLDCs and can be discussed in OCC.

KSEBL vide letter dated 17.02.2017 (Annexure-XLVII) had raised the issue of

replacement of PLCC protection coupler for Kayamkulam transmission system

maintained by PGCIL. 30th

TCC: PGCIL informed that PLCC protection coupler would

be replaced by them under their O&M head.

KSEBL vide letter dated 17.02.2017 (refer Annexure-XLVII) had raised the issue of

providing a Service Engineer at site for the maintenance of Fibre Optical Terminal


equipments at site: PGCIL stated that as per contract, the Service Engineer needs to be

available within certain time. KSEBL stated that on one of the occasion, it had taken

more than one day for the Engineer to respond and on few occasions, it was affecting

the VC connectivity. PGCIL agreed to look into the term and condition of Maintenance

Contract and M/s Tejas would be advised to adhere to it.

TSTRANSCO suggested a SPS for ICT tripping/loading at NTPC, Ramagundam. It was

agreed SRLDC & TSTRANSCO would study the scheme. The loads would be provided

by TSTRANSCO. NTPC, Ramagundam to extend cooperation for implementation of

the SPS. MS, SRPC suggested for augmentation as SPS would provide temporary relief

only. TSTRANSCO clarified that new substations are coming in that area which would

reduce the loadings of Ramagundam ICTs.

SRLDC stated that Point to Point Black Start mock exercise needs to be given more

importance and needs to be completed twice a year.

35.13.1 SRPC noted the above and suggested concerned entities to initiate action/corrective

action

36 SHARING OF TRANSMISSION CHARGES OF TRANSMISSION ASSETS OF

NATIONAL IMPORTANCE

36.1 The following had been deliberated in earlier Meetings:

Hon‟ble Commission in its Order in Petition No. 67/TT/2015 (Sharing of Transmission

charges) had stated the following in Para 30 in its Order dated 08.01.2016:

“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”.

KSEBL/TANTRANSCO had stated that the planning of this system had not been

deliberated in the Standing Committee of SR and SRPC Meetings. In the present scenario

the SR constituents were unlikely to reap any benefit from this HVDC links between NER

and NR.

Subsequently, Chairperson, SRPC vide letter dated 16.03.2016 had taken up the issue

with Chairperson, CERC.

In the ROP for date of order dt.03.03.2016, the following had been stated:

„…Accordingly, we direct that the transmission charges allowed in para 6 of this

order shall be provisionally recovered from DICs of all regions in accordance with

the provisions of Central Electricity Regulatory Commission (Sharing of Inter-State

Transmission Charges and Losses) Regulations, 2010 as amended from time to time,

subject to the final decision of the Commission in the present petition. It is further

directed that any grant/assistance received from Government of India/PSDF Fund

shall be applied to reduce the cost of the assets and consequently, the transmission

charges of these assets. We direct PGCIL to pursue the matter in the right earnest

for early release of grant/assistance.‟

In the ROP for date of hearing 19.04.2016, the following had been stated:

„………..The Commission directed the respondents, who have not filed their reply, to

file reply as a last opportunity by 29.4.2016 and the petitioner to file rejoinder, if any,


by 6.5.2016. The Commission directed the parties to comply with the directions within

the timeline specified.

4. The Commission directed to list the matter on 31.5.2016 for final arguments.‟

In the ROP of Hon‟ble CERC for date of hearing 05.07.2016 it was noted that submissions

had been made by various entities like GRIDCO, KSEBL etc and final Order was awaited.

36.2 PGCIL had filed Petition (184/TT/2016) in respect of „Determination of transmission tariff for

asset ± 800kV Biswanath Chariali -Agra HVDC Pole-II (1500MW HVDC Terminal at

Biswanath Chariali and Agra) along with Earth Electrode line and Earth Electrode Station for

both Biswanath Chariali and Agra from anticipated CoD 1.9.2016 to 31.3.2019….”. Hon‟ble

CERC in its Order dated 27.12.2016 had stated

„6. Reply has been filed by Uttar Pradesh Power Corporation Limited (UPPCL),

Respondent No. 12, vide affidavit dated 17.10.2016, BSES Rajdhani Power Limited

(BRPL), Respondent No. 22, vide affidavit dated 3.11.2016 and Kerala State Electricity

Board (KSEB), Respondent No. 35, vide affidavit dated 22.11.2016. Issues raised by

respondents will be considered at the time of grant of final tariff. After carrying out

preliminary prudence check of the AFC claimed by the petitioner, we are inclined to grant

AFC for ±800kV Biswanath Chariyali-Agra HVDC Pole-II covered in the instant petition

in terms of proviso (i) of Regulation 7(7) of the 2014 Tariff Regulations as given in para 7

of this order for the years 2016-17 and 2017-18.

………………….

9. The petitioner is further directed to file the additional information sought vide RoP

dated 17.11.2016 with a copy to respondents by 30.12.2016. The parties are directed to

complete the pleadings by 10.2.2017.

10. The matter shall be listed on 21.2.2017 for final hearing.‟


36.3 MS, SRPC informed that Hon‟ble CERC in Petition No.67/TT/2014 (date of order 07.02.2017)

had noted „……………..tariff allowed for the instant assets up to 31.3.2017 is extended for the

year 2017-18 under proviso (i) of Regulation 7(7) of the 2014 Tariff Regulations for inclusion

in the POC charges, subject to adjustment as provided under proviso (ia) of Regulation 7(7) of

the 2014 Tariff Regulations.‟

37 THOROUGH REVIEW OF ALL THE DRAWAL POINTS OF STATES FOR

DRAWAL COMPUTATIONS

SRPC vide letter dated 30.10.2015 had circulated revised methodology to identify the

node points and touch points in a node for Southern Region.

This methodology was noted in the 30th

SRPC Meeting and also in the 31st and 32

nd

CCM. As per deliberations of the 32nd

CCM, accounting based on Nodal points identified

for drawl was used for accounting of Energy in the Southern Region from 7th

November

2016 onwards.



38 IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT

SYSTEM (PMS) FOR SOUTHERN REGION

38.1 In the 26th

Meeting of SRPC 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.

38.2 In this regard, steps have been initiated to procure Protection Suite through PSDF funding. A

total of 35 licenses would be procured for the Constituents of Southern Region. After

obtaining approval for PSDF funding, tendering process for executing Protection Management

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 from Chairperson, SRPC.


38.4 It was noted that the Proposal of PMS for PSDF funding had been approved by the Monitoring

Committee and Sanction Order had also been received from MoP. Bidding documents were

under preparation.

39 POWER SYSTEM ANALYSIS GROUP (PSAG-17) MEETING HELD ON 3rd

& 4th

OCTOBER 2016 AT NTPC-SIMHADRI STPS, KALPAKA SS AND HNPCL TPS

39.1 On 6th

September, 2016, multiple trippings took place in Kalpaka – Gazuwaka – Hinduja

NPCL – Simhadri (KGHS) Corridor with Kalpaka as the epicentre. Though the triggering/

initiating cause was the failure of the Y-ph limb of Circuit Breaker (CB) of Bus Reactor -3

(BR-3) at 400/ 220 kV Kalpaka SS of APTRANSCO, certain anomalies had been observed in

the protection system operation that became manifest in the consequent multiple trippings in

the transmission network adjoining Kalpaka SS.

39.2 Keeping in view importance of KGHS Corridor and the gravity of the issues involved, a

PSAG-17 team comprising Officials from SRPC, SRLDC, KPTCL, KSEB, PGCIL (SRTS-I),

APTRANSCO, NTPC and HNPCL held their Meeting on 3rd

& 4th

October, 2016 at NTPC-

Simhadri STPS, Kalpaka SS and HNPCL TPS, and made field visits to their Control Rooms

& Switchyards.

39.3 Committee, after thoroughly analyzing various issues involved, had submitted following set of

recommendations to be complied with by APTRANSCO, NTPC-Simhadri, PGCIL (SR-I)

and HNPCL:

Revision of Bus Bar Protection (BBP) relay‟s settings & ascertaining reasons for

Breaker failure at Kalpaka SS of APTRANSCO.


Measures to sort out development of sudden & steep Over Voltage on Simhadri –

Kalpaka lines 2 & 3 & 4 at Simhadri end.

Provision of external Auto-Reclose (A/R) relays on Kalpaka bound lines at Simhadri

STPS (Stage-I).

Distance protection settings (Zone-2 & Zone-4) for the lines emanating from Gajuwaka

- Kalpaka - Simhadri – HNPCL Corridor.

Provision of Line differential Protection on all 400 kV transmission lines

interconnecting Gazuwaka SS (PGCIL-STRS1), Simhadri STPS (NTPC), Kalpaka SS

(APTRANSCO), and Hinduja TPS (HNPCL).

Providing for proper substation maintenance equipment like DCRM, PPI test kit,

thermo-vision scanning camera at Kalpaka SS of APTRANSCO.

Provision of GPS/ Time synchronization facility in all 220 kV & above substations/

generation switchyards in Gazuwaka – Simhadri – Kalpaka Corridor.

39.4 Additionally, on request of NTPC-Simhadri, system studies pertaining to power evacuation

from Kalpaka – Gazuwaka – HNPCL – Simhadri (KGHS) Corridor were carried out and

presented. Also field visits to Control Room & Switchyard of NTPC-Simhadri STPS,

Kalpaka SS and HNPCL TPS had been undertaken to get first-hand information of the

adopted relay settings & protection practices being followed.

39.5 The compliance report is given at Annexure-XLVIII


APTRANSCO, PGCIL (SR-I), NTPC-Simhadri & HNPCL were requested to initiate steps

to comply with recommendations given, especially line differential protection, at the

earliest.


40 AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE

TRANSMISSION LINES OF SOUTHERN REGION

40.1 Majority of faults that occur on transmission lines are of transient nature; hence provision

of Auto-Reclosure certainly helps not only in preventing forced outage of the subject

transmission line, but also in averting cascade trippings, in some cases, of adjacent

transmission lines due to consequent over-loading.

40.2 Provision for Auto-Reclosure is also mandated by Regulation 43 (4) (c) of CEA Technical

Standards for Construction of Electrical Plants and Electric Lines, 2010, which has force of

law. Therefore, it is in the interest of grid security that all Constituents implement auto-

reclosure feature on all 220 kV & above transmission lines in their respective control areas.

Any exceptions to this needed to be properly justified.

40.3 This issue had been discussed in PCSCM-60 held on 22.12.2016, wherein the logics to be

used for implementing A/R was clarified. All Constituents, in whose 220 kV & above


network A/R had not yet been implemented, were requested to furnish an action plan for

providing the same by PCSC-61 Meeting schedule to be held on 27.01.2017.

40.4 SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed A/R issues for

discussion.


Status of implementation of A/R (excluding Radial feeders & Cables) as furnished by

SR-Constituents is given at Annexure-XLIX Action plan furnished by SR-Constituents

for implementing A/R on the transmission lines, where it is presently not in service is

given at Annexure-L.

APGENCO, APTRANSCO, TSGENCO, TSTRANSCO, NLCIL, NTPC-Ramagundam

and BHAVINI had not furnished the Action Plan for implementing Auto-Reclosure in

their 220 kV & above voltage level transmission lines.

TCC noted the following :

All above Constituents agreed to furnish the detailed Action Plan for implementing A/R

in their 220 kV & above voltage level transmission lines by next PCSC-62 Meeting

scheduled to be conducted on 15th

March 2017.

All SR-Constituents were kindly requested to take steps to implement A/R in their

respective networks at the earliest.


41 STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY

RESOURCES INTO THE GRID

41.1 The proposal had been approved by Monitoring Committee and sanction Order has been

issued by MoP. Bidding Documents have been floated through E Procurement mode. The

last date for receipt of bids is 2nd

March 2017. Nominations will be sought from utilities in

Southern Region for the study programme on integration of RES. Nominations from utilities

will also be sought to two Assessment Committees for this scheme. While one Assessment

Committee will carry out technical scrutiny of the proposals received, the second Assessment

Committee will carry out scrutiny of the commercial proposals.


41.3 MS, SRPC informed that NIT had been floated. Technical/Price bids would be opened in first

week of March 2017. Nominations would be sought from utilities shortly in this regard.

42 SPECIAL MEETING WITH M/S KPCL HELD ON 27.10.2016 AT SRPC,

BENGALURU

42.1 A Special Meeting was conducted on 27th

October, 2016 at SRPC Secretariat, Bengaluru to

deliberate on the issues concerning hydro power stations (HPS) of M/s KPCL in the context

of Grid Disturbances (GD‟s) during August – October, 2016 that had led to complete outage

of few hydro power stations of M/s KPCL.

42.2 In the Meeting, apart from specific issues that had caused GD‟s at various hydro power


stations, general issues required to be given attention by KPCL to avoid recurrence of such

events in future were also discussed. Deliberations revolved around the following issues:

Ensuring proper protection setting of all newly commissioned & to-be-commissioned

relays.

Auto-Reclosure implementation on all 220 kV lines emanating from KPCL‟s generating

stations.

Providing for Double Main-Bus operation at all 220 kV HPS‟s of KPCL.

Provision of stand-alone Disturbance Recorder (DR) & stand-alone Event-Logger (EL)

at all HPSs of KPCL.

Station-specific recommendations covering 220 kV Nagjheri PH, 220 kV Kadra PH,

220 kV Sharavathy Tail Race PH, 220 kV Varahi UGPH and 220 kV Sharavathy PH.

Additionally, following running operational issues of KPCL were also discussed:

RGMO performance

RGMO status point extension to SLDC/SRLDC

PSS tuning related issues

CoD of Bellary TPS (Unit-III), and Yeramarus TPS (Unit-I)

Mock-Drill of Black-Start restoration


Compliance Status as furnished by M/s KPCL vide their letter dated 26.11.2016 is at

Annexure- LI. MS, SRPC had suggested KPCL to look into the recommendations of

providing for Double Main-Bus operation at all 220 kV HPSs of KPCL as a long term

measure.

43 IMPLEMENTATION OF LINE DIFFERENTIAL PROTECTION (LDP)

43.1 NPC vide letter No. 4/ MTGS/ NPC/ CEA/ 2016 dated 27.10.2016 had requested to discuss

implementation of Recommendation on Line Differential Protection of the Sub-Committee

on Relay/Protection under Task Force for Power System Analysis under contingencies

(Para14 in Section-6 of the report under Relay setting guidelines for Transmission lines).

43.2 In this regard, the issue was discussed by PCSC forum in their 59th

Meeting held on

22.11.2016. The deliberations focused on the logic to be followed for LDP implementation,

fit-cases for LDP implementation, and general guidelines for implementing LDP.

Application of System Studies to ascertain the fit-cases for implementing LDP was also

explained (Ref: MoM of PCSC-59 issued vide SRPC letter no: SRPC/ SE-III/ PCSC-59/

2016/ 7890 – 23 dated 08.12.2016)

43.3 Subsequently, the issue had been discussed in the 6th

Meeting of NPC held on 19.12.2016 at

Bengaluru, where it was decided that the same sub-group formed for PSS would also look

into various aspects of implementing LDP.



44 PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS

44.1 In recent times insulator tracking has been observed in Transmission lines and Substations

located in the coastal and polluted areas and SRPC vide letter dated 05th

May 2016 had

communicated to the concerned in this regard. Transmission Lines and Substations in the

most vulnerable terrain, coastal and polluted areas were to be categorized for monitoring to

ensure that Patrolling and Maintenance is being carried out as per Patrolling guidelines.

Format for furnishing details of schedule / Patrolling and Maintenance carried out of the

critical Transmission lines and Substations had been enclosed.

44.2 Concerned entities need to kindly initiate/continue necessary steps to ensure that Patrolling

and Maintenance is carried out regularly as per the Patrolling Guidelines.

44.3 SRPC noted the above and suggested to maintain sustained efforts in this direction.

45 7th

MEETING OF NATIONAL RELIABILITY COUNCIL FOR ELECTRICITY HELD

ON 07.12.2016 AT NRPC, NEW DELHI

45.1 In accordance with the decision taken in the 6th

Meeting of NRCE, two sub-groups had been

constituted to work on the following (Ref: MoM of NRCE-6 issued vide NPC letter

no:3/NRCE/NPC/CEA/2016/35-63 dated05.01.2016)

Sub-Group to finalize Protection and Communication Standards

Sub-Group for the purpose of determination of TTC/ATC/TRM and to suggest a clear-

cut methodology for calculation of ATC, TTC & TRM to POSOCO to comply with.

45.2 Previously all RPC‟s were represented in the second sub-group only. In the 7th

NRCE

Meeting, it was agreed to invite Members from all RPCs in the first sub-group Meetings

also as Special Invitees.

45.3 SRPC Secretariat vide letter dated 25.01.2017 (Annexure-LII) had taken up certain issues

in respect of TTC/ATC and congestion with NRCE.


46 SRPC REPORT ON “EFFECT OF DELAYED CLEARANCE OF FAULT ON

TRANSMISSION SYSTEM”

46.1 Hon‟ble CERC vide their Order dated 14.06.2016 in respect of petition no: 9/SM/2014 on

“Investigation of tower collapse and load crash in northern region on 30.05.2014” and petition

no: 10/SM/2015 on “Investigation of line outages due to tower collapse in northern region

during April-June, 2015” had noted that delayed clearance of faults is a serious issue and

directed RPC‟s to examine the cases of delayed clearance of faults on the transmission system

during last two years in respective region, and submit an analysis report on the same.

With respect to above, SRPC had considered the instances of delayed fault clearance that


occurred between April 2014 – May 2016 from SRLDC Database, and sought comments from

concerned SR-Constituents. Based on the inputs furnished by SR-Constituents, and available

regulations/ guidelines/ reports/ literature on the subject, a report had been compiled and

submitted to Hon‟ble CERC vide SRPC letter dated 14.12.2016. This report was included in

MoM of PCSC-60 issued vide SRPC letter dated 06.01.2017.

47 PROTECTION AUDIT OF 400 KV ALUNDUR SS OF PGCIL (SR-II) AND 230 KV

ALUNDUR S/S OF TANTRANSCO

47.1 Hon‟ble CERC vide Order dated 27.04.2015 in respect of Petition No.95/MP/2015 dated

09.04.2015 had directed SRPC to submit bi-monthly report of periodic protection audit

details to the Hon'ble Commission.

47.2 In this regard, for the period covering 01.11.2016 – 31.12.2016, the following substations had

been protection audited:

Sl

No

Name of the substation

audited

Date of

Protection

Audit

Audit Team

Composition

1 400 kV Alundur SS of PGCIL

(SR II)

16.12.2016 SRPC, SRLDC &

KPTCL

2 230 kV Alundur SS of

TANTRANSCO

17.12.2016 SRPC, SRLDC,

PGCIL & KPTCL

47.3 Remarks of the protection team given at Annexure-LIII were submitted to Hon‟ble CERC

vide SRPC letter dated 02.01.2017.

PGCIL (SR-II) and TANTRANSCO were requested to take suitable action to comply with

the remarks given.

47.4 In this regard, Compliance Status furnished by PGCIL (SR-II) is given at Annexure-LIV.


48 SPECIAL MEETING ON NEYVELI GRID DISTURBANCE

48.1 A Special Meeting had been conducted on 03rd

January 2017 in SRPC Secretariat,

Bengaluru with Officials of TANTRANSCO, NLCIL, Puducherry, ST-CMS and SRLDC

along with participation of KPTCL & KSEBL to deliberate on various issues involved in the

Neyveli Grid Disturbance that occurred on 25th

November, 2016.

48.2 Compliance status is given at Annexure-LV.



49 PENDING IMPLEMENTATION OF RECOMMENDATIONS OF PROTECTION

COORDINATION SUB-COMMITTEE (PCSC) OF SRPC

49.1 Recommendations given in various PCSC Meetings to SR-Constituents are being sent

regularly to the concerned Constituents for implementation. Update of the consolidated list

of pending PCSC recommendations (up to the 60th

Meeting) for implementation by SR-

Constituents is enclosed in the minutes of PCSC.

49.2 SRPC noted the above and suggested appropriate time bound action by the entities to close

all the issues.

50 COMMERCIAL COMMITTEE ISSUES

50.1 Following issues had been discussed in the CC Meetings and brought to the attention of

SRPC/TCC:

Audit of SR UI/Deviation Account &Reactive Energy Pool Account

Assessment of Metering requirement

CCM forum requested SRTS I, PGCIL, STUs, Generators and IPPs to submit the SEM

requirements and procurement plan for the power system elements as per CEA Metering

regulations for the upcoming projects to the SRLDC and SRPC Secretariat .

Non Availability of SEMs as per CEA metering regulations

In the 32nd

Meeting of CCM, SRTS II, PGCIL had stated that irrespective of the

ownership of the bay and line, the owner of the sub-station shall install the SEM at their

stations. Consolidated list of locations where SEMs are not available as per CEA Metering

Regulations is given below:

S.No Element Non availability of

SEM

To be installed by

1 MAPS: GTs (HV side) Stand By CTU/MAPS

2 Vallur : 400 kV NCTPS lines 1

& 2

Check NCTPS/CTU

3 400 kV UPCL-Hassan line

1&2

UPCL CTU/KPTCL/UPCL

4 400 kV Nelamangala-Hassan

line

Nelamangala CTU/KPTCL

5 400 kV Talaguppa-Hassan Line Talaguppa KPTCL

6 400 kV Guttur-Hiriyur lines

1&2

Both Guttur and Hiriyur CTU / KPTCL

7 Bonakaalu - Chillakallu lines

1&2

Bonakaalu end of 132

kV Line

TS

8 400kV Hiriyur-BTPS lines

1&2

Both Hiriyur and BTPS KPTCL


Non-compliance / pending issues as per 3rd

Meeting of Nodal Officers for SEM Data

Coordination and 32nd

CCM

Sl No Description 32nd

CCM deliberations Status

a Replacement of

SEMs at

Thiruvalam and

Theni

TANTRANSCO informed

that SEMs arrived at the site

and they were waiting for LC

to install the SEM.

The forum requested

TANTRANSCO to take up

with SRLDC to avail the LC

to replace the SEMs at the

earliest and inform SRPC.

TANTRANSCO

yet to install the

SEMs.

b Non receipt of

SEM data from

Kadra, Kodasalli,

Guttur and

Nelamangala.

KPTCL yet to install the

SEM.

KPTCL yet to

install the SEMs.

Approval of Metering Scheme for new Generation and Transmission scheme

All SR constituents had been requested to submit the Metering scheme to SRLDC / SRPC

with the requisite documents to get it approved in the CCM of SRPC.

Submission of C1-C4 formats for New Element Charging

As per the new NLDC procedure, complete C1-C4 format needs to be submitted, soon

after successful trial operation, to declare COD.

Failure to intimate new Bay charging details to SRLDC

All entities had been requested to inform SLDC/SRLDC and the other end utility (if

applicable) regarding the bay changing works etc, that affect commercial accounting

issues to have effective and correct accounting system.

Non-compliance/Pending Issues as per 3rd

Meeting of Nodal Officers for SEM Data

Coordination

It was noted that certain SEM issues raised were yet to be resolved.

50.2 SRLDC vide letter dated 07.02.2017 (refer Annexure-XII) had proposed following issues

for discussion:

Replacement of defective meters/ high time drift (Say more than 10 minutes) meters and

action for attending the time drift in meters with time drift less than 10 minutes.

Reconciliation and confirmation of STOA transactions payments made, TDS deduction

etc to SRLDC by 10th

of following month.

50.3 KSEBL vide letter dated 31.01.2017 (refer Annexure-XVIII) had stated that there was

mismatch in the scheduled energy for the MTOA transaction between MPL and KSEBL for

the month of August 2016 in the REAs of SRPC and ERPC. On 1st August 2016 while


revision was carried out at SRLDC (Block 40 to 82), corresponding revision has not been

taken into account by ERPC. ERLDC has not issued any revision for these blocks. It has

been stated that energy account of ERPC needs to be corrected.


Regarding KSEBL issue (MTOA transaction in August 2016), SRLDC had informed that

the matter has been taken up with ERLDC.

KPTCL had informed that they had requested for 11 SEMs urgently from PGCIL. SR-II,

PGCIL informed that they had purchased spares SEMs for their use but 11 nos would be

provided to KPTCL.

TCC had noted the above issues and suggested concerned entities to take necessary steps

to close the issues.


51 ISSUES IN BILLING OF GENERATING STATIONS OWNED BY NTPC (TARIFF

PERIOD 2014-19)

51.1 KSEBL vide letter dated 31.01.2017 & 17.02.2017 (refer Annexure -XVIII & XLVII) had

stated that NTPC have adjusted the total moisture content of coal resulting in increase of

working capital and hence increase in AFC. Once the adjustment has been made by CERC

and working capital for the entire tariff period is fixed, further adjustment in working capital

cannot be allowed. NTPC cannot make further adjustments and claim different amount from

the beneficiaries. It is stated that claim of NTPC is not in line with the Regulations and

Orders of CERC.


KSEBL had stated that there was discrepancy in AFC computation as there was

duplication of the moisture content adjustment in the Tariff Orders.

NTPC had stated that adjustment of GCV for moisture content and billing is as per

CERC Order and CERC Regulations. It was mentioned in the Order of Tariff that „6.

Adjustment on account of coal received at the generating station for equilibrated basis

(Air dried) in the billed GCV Of Coal India‟ is „To be calculated by the petitioner

based on the adjustment formula‟ and „Rate of energy charge ex-bus‟ is „ to be revised

as per the figures at Sr. No. 6‟.

TCC had observed that NTPC computation appeared to be in line with CERC

Order/Regulations.


52 TPCIL REQUEST TO EXEMPT DEVIATION CHARGES

52.1 TPCIL vide letter dated 07.01.2016 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 28.12.15 to 03.01.16.


52.2 Issue was deliberated in the 31st 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‟. In the 6th

Meeting of NPC held on

19.12.2016, NPC had finalized the methodology and it would be put to CERC.

52.3 TPCIL had filed a Petition No.193/MP/2016 which was heard on 19.01.2017 and admitted.

The petition was listed for hearing on 16.03.2017.


53 SCHEDULING OF NTPC RAMAGUNDAM SOLAR POWER PLANT (10 MW)

53.1 A Special Meeting was held on 17th

November 2015, to facilitate scheduling by SRLDC

and identifies certain prerequisite criteria to be ensured by NTPC. The issue is being

followed up in the OCC Meetings.

53.2 The following had been noted in earlier Meetings:

NTPC had informed that any decision regarding scheduling domain would be as per

Regulations. For a small plant of 10 MW, it was not appearing feasible for two states

have a share in it. Concurrence from Andhra Pradesh and Telangana had been received

in this regard. Some power could be given to Andhra Pradesh from other NTPC Solar

plant (NP Kunta) while this plant could be dedicated solely to Telangana.

SRPC had stated that in that case, MoP may need to be approached for necessary

amendment with regard to unallocated power linked with this project.


discussion:


NTPC informed that concurrence from AP and TS has been received and they would be

approaching MoP in this regard.

54 SCHEDULING OF UNITS BELOW TECHNICAL MINIMUM AND OTHER ISSUES

54.1 Issue of scheduling the units below technical minimum and other issues were deliberated in

detail in 29th

TCC/30th

SRPC Meetings. After deliberations, it was agreed that CEA‟s advice

would be sought for smoother facilitation of renewable integration.

54.2 SRPC Secretariat vide letter dated 29.08.2016 (Annexure-LVI) had taken up the issue with

CEA. Subsequently, CEA had informed that major issues were covered under Committee of

Merit Order Operation and Must Run Status for Renewable.


SRLDC had enquired about the action to be taken during this wind season.

It was noted that the Procedure on Technical Minimum/Compensation may come out

shortly.



55 MONITORING OF SCHEMES FUNDED FROM PSDF

55.1 In the 6th


website) it was noted that in a Meeting held on 29.04.2016 chaired by Joint Secretary (OM),

MoP to review the status of implementation of the schemes funded from PSDF, it was felt

prudent that respective RPC Secretariat monitor the schemes approved in its region, in

addition to the Monitoring Group at Central level, as part of monthly Meetings, in view of

slow progress of the implementation of the schemes.

55.2 After deliberations, it was decided that NPC Secretariat would put up Agenda on monitoring

of schemes funded from PSDF for deliberation in the OCC Meetings of RPCs. RPCs agreed

to take up monitoring of schemes funded from PSDF in monthly OCC Meetings on regular

basis for updating the status of implementation.

55.3 In the 127th

OCC Meeting, NPC representative had appraised the OCC on monitoring

requirements. All concerned entities are kindly requested to ensure needful.


MS, SRPC had stated that the PSDF funded schemes were to be monitored in the OCC as

per the directive of MoP through CEA.

NPC had expressed concern that implementation of projects and disbursement was not as

desired. In respect of KPCL, the progress was slightly better. With regard to TN, for two

schemes, amount had been drawn only for one scheme. For Puducherry, the scheme had

been sanctioned in August 2015 while the agreement was still to be signed.

TSTRANSCO had stated that the first batch of sanction had a time period of one year

from the date of sanction. For the first batch scheme, 50 % works were over and they

required extension to complete the works. NPC had informed that as noted in the last

review Meeting, TSTRANSCO needed to approach NLDC for extension.

APTRANSCO had stated that all the required documents for disbursement of the

installment has been furnished to NLDC and the payment release needs to be expedited.

55.5 SRPC urged the agencies to take urgent steps to ensure needful.

56 SALE OF URS POWER BY NLC STAGE-II

56.1 In the 126th

OCC Meeting, TSTRANSCO had expressed concern that NLC was selling power

outside for a price less than variable charge (Rs.2.598/unit for the month of December 2016).

After giving consent, they were losing the chance to recall the surrendered power and selling

below variable price which was against the spirit of Tariff policy.


57 SCHEDULING OF KAMUTHI SOLAR PARK

57.1 Two Meetings had been convened on 03.11.2016 and 23.12.2016 at SRPC, Bengaluru to

discuss scheduling and dispatching responsibility in respect of Adani Solar Power Project at

Kamuthi in Tamil Nadu. Minutes of the two Meetings are available at SRPC website. In the


Meeting held on 23.12.2016, the following was concluded:

„After deliberation it was decided that M/s. AGEL would obtain legal advice and

submit the same to SRPC & SRLDC. Subsequently SRPC would refer the matter to CEA

for legal advice. Tamil Nadu was also requested to consider furnishing their inputs to

SRPC/CEA at the earliest.‟

57.2 Legal opinion from M/s AGEL had been received.


57.4 It was noted that legal opinion of M/s AGEL and POSOCO had been referred to CEA.

58 SETTLEMENT FOR THE PERIOD PRIOR TO BIFURCATION OF AP AND

TELANGANA

58.1 A Meeting was held on 25.10.2016 At Hyderabad to deliberate the settlement of bills for the

period prior to AP and Telangana and other issues. Minutes of the Meeting are available on

SRPC website.


58.3 It was noted that there were some issues in respect of PGCIL payments for AP and Telangana

and a separate meeting at Hyderabad would be arranged.

59 AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM

59.1 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.

59.2 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.‟

59.3 In the 29th

Meeting of SRPC, TANTRANSCO had stated that as discussed in earlier SRPC

Meeting, all constituents had been suggested to jointly implead but no action has been

taken. They were in the process of invoking the Bank Guarantee.



59.5 Director (D), TANGEDCO informed that after CERC‟s Order referred in the agenda, M/s

Reliance had approached APTEL. Revised cost submitted by the M/s Reliance is around

2.5 to 3 times the original cost. APTEL had advised Reliance to approach all the LTTCs for

seeking consent for Reliance to carry out the works at enhanced cost. Reliance had

convened a meeting but none of the LTTCs had attended and now they have taken up the

issue through letters. Next hearing in APTEL was scheduled in 1st week of April 2017.

59.6 Director (T&SO), KSEBL suggested for Joint Study to assess requirement of Talcher II

augmentation system in the present scenario.

60 GRID OPERATION

Salient Achievements

11.4 BUs Wind energy was evacuated in Tamil Nadu in 2016 with considerable

efforts of TANGEDCO, TANTRANSCO & SRLDC.

Efforts of TANTRANSCO, TANGEDCO, NTECL, PGCIL, SRLDC & SR

constituents during Vardha cyclone and system revival.

Workshop on AGC followed by feedback / suggestion session on Ancillary Services

Implementation was conducted by NLDC on 03.10.2016.

Workshop on PoC was conducted by SRPC and SRLDC on 14.12.2016 for better

understanding of PoC concepts, need for data validation, demand forecast, internal

generation, net load, truncation etc.

AP crossed 3,000 MW of combined wind and solar installed capacity as on

30.11.2016 and the deviation limit was increased to 250 MW from 200 MW w.e.f.

01.12.2016.

Telangana crossed 1,000 MW of combined wind and solar installed capacity as on

31.12.2016 and the deviation limit was increased to 200 MW from 150 MW w.e.f.

01.01.2017.

Efforts of TSGENCO, TSSLDC and SRLDC for successfully completing the MVAR

testing at Nagarjunasagar on 17.09.2016.

Workshop was conducted by SRLDC at MAPS for NPCIL stations on grid aspects on

23.01.2017.

POSOCO was created as an separate entity with effect from 03.01.2017.

BSRP workshop for TN was completed on19.12.2016 by SRLDC

Reactive power document of SR 2016 released on 30.12.2016 by SRLDC

Black start restoration procedure of SR 2017 released on 30.12.2016 by SRLDC

60.1 Grid Events/ Highlights during August 2016

Andhra Pradesh met a demand of 8270 MW on 23.08.2016 which was maximum till date

Telangana met a demand of 8405 MW on 12.08.2016 which was maximum till date

Southern Region witnessed highest ever wind power generation in August 2016 (153.9 MU

on 16.08.2016).

Andhra Pradesh wind generation met a maximum of 24.08 MU on 03.08.2016.

Karnataka wind generation met a maximum of 39.72 MU on 03.08.2016.

Tamil Nadu wind generation met a maximum of 4906 MW on 29.08.2016 at 16:00 hours.


Tamil Nadu wind generation met a maximum of 97.35 MU on 16.08.2016.

Tamil Nadu solar met a maximum of 863 MW on 28.08.2016 at 12:00 hours.

Tamil Nadu solar generation met a maximum of 5.647 MU on 11.08.2016.

KKNPP Unit II of NPCIL was synchronized to Grid on 29.08.2016.

Bidadi-Tumkur (TBCB) line was connected to Bidadi and Nelamangala (by opening of

Bidadi - Nelamangala line) as temporary rearrangement and made operational (trial

operation completed on 24.08.2016).

Kudgi ICT II was charged on 06.09.2016 by NTPC.

Unit II of HNPCL in Andhra Pradesh, of installed capacity 520 MW was declared COD

from 00:00 hours of 03.07.2016.

2nd Circuit stringing on 220 kV Garividi – Tekkali feeder in Srikakulam Dist of 92 ckm was

commissioned on 12.08.2016 by APTRANSCO.

230/132kV, 100 MVA capacity transformer at 220 kV SS at Kosagi was commissioned on

22.08.2016 by TSTRANSCO.

SR II, Power grid vide letter dated 31.08.2016 had informed that consequent to the

successful completion of Trial Operation, the following asset under Transmission System

associated with “System strengthening – XX Southern Region Grid” have been put under

Commercial Operation w.e.f 00:00 hrs of 31st August 2016 in terms of Clause 4 of CERC

(Terms and Conditions of Tariff Regulations 2014):

1 x 125 MVA, 400/220/33 kV ICT at Somanahalli Substation along with associated

bays and equipments.

CEA vide letter dated 9th

September 2016 had enclosed MoP letter dated 7th

September

2016. MoP has withdrawn 50 MW unallocated power of Andhra Pradesh from KKNPP

first Unit and the power is added to the Southern Regional pool of unallocated power for

utilization by the states /UTs. The revised allocation (Firm + Unallocated) in percentage

from Central Generating Stations (CGS) of SR to the beneficiaries were implemented from

00:00 hrs of 14th

September 2016 till further orders.

60.2 Grid Events/Highlights during September 2016

TSTRANSCO met a demand of 8444 MW on 09.09.2016 which was maximum till date .

TSTRANSCO had a Maximum wind generation of 87 MW & 1.36 MU on 18.09.2016

which is till date maximum.

TSTRANSCO had a Maximum Solar generation of 483 MW on 29.09.2016 which is till

date maximum.

TSTRANSCO had a Maximum wind generation of 3.37 MU on 08.09.2016 which is till

date maximum.

220/33 kV SS at Singotam in Mehaboobnagar Dist of capacity of 31.5 MVA was

commissioned on 02.09.2016 by TSTRANSCO.

220/132 kV SS at Nagole in R.R. Dist of capacity of 100 MVA was commissioned on


220/132 kV features at 132 Sitapuram Sub Station in Nalgonda Dist capacity of 160 MVA

was commissioned on 19.09.2016 by TSTRANSCO.

220 kV LILO from 220 kV Wanaparthy-Regimanugadda line to proposed 220/132 kV SS

Singotam in Mehaboobnagar Dist of 10.4 ckm was commissioned on 02.09.2016 by

TSTRANSCO


220 kV D/C line from Puluchintala Hydro Electric station switchyard to Sitapuram

switching station in Nalgonda Dist of 15.74 ckm was commissioned on 19.09.2016 by

TSTRANSCO.

220 kV line from Ghanapur to Nagole SS in R.R. Dist of 40.38 ckm was commissioned on


400 kV Kamuthi – Karaikudi line was commissioned on 08.09.2016 at 15:58 hrs by

TANTRANSCO.

GMR Vemagiri Bus Reactor in AP was commissioned on 11.09.2016 at 16:38 hrs.

GT II at SGPL was commissioned on 16.09.2016 at 17:25 hrs by SGPL.

Kamuthi ICT IV was commissioned on 19.09.2016 at 18:23 hrs by TANTRANSCO.

125 MVA Bus Reactor II at NTPC Kudgi was commissioned on 21.09.2016 at 17:01 hrs

by NTPC.

400 kV Salem – Dharmapuri- 1 was commissioned on 21.09.2016 at 16:35 hrs.

400 kV Salem – Dharmapuri- 2 was commissioned on 21.09.2016 at 18:10 hrs.

400 kV Kudgi – Tumkur – 1 &2 Trial operation completed on 23.09.2016.


successful completion of Trial Operation, the following asset under Transmission System

associated with “System strengthening – XX Southern Region Grid” have been put under

Commercial Operation w.e.f 00:00 hrs of 23rd

September 2016 in terms of Clause 4 of

CERC (Terms and Conditions of Tariff Regulations 2014):

1 x 500 MVA, 400/220/33 kV ICT at Mysore Substation along with associated bays

and equipments.

60.3 Grid Events/Highlights during October 2016

1.5 MW of windmill capacity (Private sector) was added in Tamil Nadu during October

2016.

220 kV SS Nellore in SPSR Nellore Dist of 2 x 160 + 1 x 100 existing MVA was

commissioned on 02.10.2016 by APTRANSCO with augmented capacity of 3 x 160

220 kV SS Chittoor in Chittoor Dist of 3 x 100 existing MVA was commissioned on

05.10.2016 by APTRANSCO with augmented capacity of 2 x 100 + 1 x 160 MVA.

220 kV D/C 42 Ckm LILO line from Miryalagudda – Kammam ckt-I @ the proposed

400/220/132 Suryapet SS in Nalgonda Dist was commissioned on 07.10.2016 by

TSTRANSCO.

220 kV D/C 48 Ckm LILO line from Miryalagudda – Kammam ckt-II @ the proposed

400/220/132 Suryapet SS in Nalgonda Dist of was commissioned on 07.10.2016 by

TSTRANSCO.

400 kV Nagapattinam-Dharmapuri -1 was commissioned on 21.10.2016 at 21:57 hrs.

400 kV Nagapattinam-Dharmapuri -2 was commissioned on 21.10.2016 at 21:05 hrs.

400 kV Coastal-Tuticorin Pooling Station-1 was commissioned on 29.10.2016 at 21:32

hrs by CEPL.

400kV Coastal-Tuticorin Pooling Station 2 was commissioned on 27.10.2016 at 16:57

hrs by CEPL.


successful completion of Trial Operation, the following asset under “Sub Station

Extension works associated with transmission required for evacuation of power from


Kudgi TPS (3 X 800MW in phase-I) of NTPC Limited” have been put under

Commercial Operation w.e.f 00:00 hrs of 24th

September 2016 in terms of Clause 4 of

CERC (Terms and Conditions of Tariff Regulations 2014).

2 Nos 400kV Line bays at Narendra (New), 2 Nos 400 kV Line bays at

Madhugiri (Tumkur), 2 x 63 MVAR (fixed) line reactors (with 600 ohm

NGRs) at Narendra (New) & 2 x 63MVAR (fixed) line reactors (with 600 ohm

NGRs) at Madhugiri (Tumkur) for Narendra (New) – Madhugiri (Tumkur) 765

kV D/c line (initially charged at 400kV).

Declaration of Commercial Operation date of Nagapattinam Pooling Section-Salem

765 kV D/C line under “Transmission system associated with IPPs of

Nagapattinam/Cuddalore Area-Package-A”

Power grid NM Transmission LTD vide letter dated 23.10.2016 had informed that on

successful completion of twenty four (24) hours of connection with the interconnection

facilities the following element is put under commercial operation w.e.f. 00:00 hours of

23rd

October 2016 and accordingly POWERGRID NM Transmission Limited (Formerly

Nagattinam Madhugiri Transmission Company Limited) is entitled for all benefits

envisaged in the aforesaid TSA.

Nagapattinam Pooling Station-Salem 765 kV D/C line (initially charged at 400

kV).

Salem-Madhugiri 765kV S/C transmission line of the project is under construction

and the COD shall be declared separately.


successful completion of Trial Operation, the following asset under “Transmission

system associated with Coastal Energen Private Limited & Ind-Bharat Power (Madras)

Limited LTOA Generation Projects in Tuticorin Area – Part-B” have been put under

Commercial Operation w.e.f 00:00 hrs of 23rd

October 2016 in terms of Clause 4 of


400 kV Salem Pooling station (Dharmapuri) – Salem 400kV D/C line along with

new 765 kV/400kV Pooling Station at Salem (Dharmapuri) (initially charged at

400 kV) and Bay Extensions at Salem 400/220 kV existing Substation.


successful completion of Trial Operation, the following asset under “Common

Transmission Scheme associated with ISGS Projects in Nagapattinam/Cuddalore area

of Tamil Nadu Part-A1(b)” in Southern region have been put under commercial

operation w.e.f 00:00 hrs of 23rd

October 2016 in terms of Clause 4 of CERC (Terms

and Conditions of Tariff Regulations 2014).

2 Nos 400kV bays each at Nagapattinam pooling station and Salem New

(Dharmapuri) for terminating Nagapattinam Pooling Station-Salem New

(Dharmapuri) 765 kV D/C Line (Initially charged at 400 kV) being

implemented under tariff based bidding and 1no. 63 MVAR line reactor at

Nagapattinam Pooling Station and Salem New (Dharmapuri) each for both

circuits of Nagapattinam Pooling Station – Salem New (Dharmapuri) 765kV

D/C Line (Initially charged at 400kV).




system associated with Coastal Energen Private Limited & Ind-Bharat Power (Madras)

Limited LTOA Generation Projects in Tuticorin Area – Part-B” have been put under

Commercial Operation w.e.f 00:00 hrs of 13th

November 2016 in terms of Clause 4 of


Tuticorin Pooling station – Salem Pooling station 765 kV D/C line (initially

charged at 400kV) along with bay extensions at Salem Pooling Station and

Tuticorin pooling station and 80 MVAR Line Reactors at each end of both

circuits of Tuticorin Pooling station – Salem Pooling Station 765kV D/C line

(Initially charged at 400kV).

60.4 Grid Events/Highlights during November 2016

6.5 MW of windmill capacity (Private sector) was added in Tamil Nadu during

November 2016.

220 kV DC/SC line from Shapuram to Subbarayanpalli in Ananthapur Dist of 9.85 ckm

was commissioned on 04.11.2016 by APTRANSCO.

220 kV DC/SC line from Boksampalli to Shapuram Switching Station in Ananthapur

Dist of 7.32 ckm was commissioned on 04.11.2016 by APTRANSCO

220/132/33 kV Boksampalli SS in Ananthapur Dist with 163 MVA capacity was


220/33 kV Subbarayunpallin SS in Ananthapur Dist with 100 MVA capacity was

commissioned on 05.11.2016 by APTRANSCO

220 kV SS Parchur in Prakasam Dist of Existing 2 x 100 MVA was commissioned on

05.11.2016 by APTRANSCO with augmented capacity of 3 x 100 MVA.

220 kV SS Gunadala in Guntur Dist of Existing 3 x 100 MVA was commissioned on

11.11.2016 by APTRANSCO with augmented capacity of 2 x 100 + 1 x 160 MVA.

220 kV Line NTPC-IV feeder to Malayalapally 220 kV SS (Ramagundam) circuit -1

with one Ckm was commissioned on 23.11.2016 by TSTRANSCO.

220/132/33 kV Miyapur SS in Hyderabad Dist was commissioned on 11.11.2016 by

TSTRANSCO with augmented capacity of 160 MVA.

400 kV Urvukonda-Veltoor-2 was commissioned on 18.11.2016 at 14:32 hrs by

TSTRANSCO.

Additional capacity of 100 MVA 3rd

Auto Transformer was commissioned at 230/110

kV Cuddalore SS by TANTRANSCO on 19.11.2016.


successful completion of Trial Operation, the following asset under “System

strengthening in Southern region - XXIII” have been put under Commercial Operation

w.e.f 00:00 hrs of 18th

December 2016 in terms of Clause 4 of CERC (Terms and

Conditions of Tariff Regulations 2014).

1 x 125 MVAR 400 kV Bus reactor along with associated bay and equipments

at Hassan 400/220 kV Sub station

60.5 Grid Events/Highlights during December 2016

Wind Mills of 2 MW capacity (Private sector) was added in Tamil Nadu during

December 2016.


Wind Mills of 42 MW & 40 MW Capacity was added in Andhra Pradesh during

November 2016 & December 2016 respectively.

Solar Capacity of 10.20 MW was added in Andhra Pradesh during November 2016

Wind Mills of 38 MW Wind Capacity were added in Karnataka during December 2016

Solar capacity of 52 MW was added in Karnataka during December 2016

220 kV UG Cable from Ghanapur – Malkaram DC line to Moulali Substation in

Rangareddy Dist of 17.694 ckm was commissioned on 01.12.2016 by TSTRANSCO.

220 kV D/C line from 220/132 kV Durshed SS to 220/132 kV Sircilla SS of 134 ckm

was commissioned on 15.12.2016 by TSTRANSCO

220 kV LILO line from Chillakallu – Narketpally to 400kV Suryapet S/S in Nalgonda

Dist of 24 ckm was commissioned on 21.12.2016 by TSTRANSCO.

100 MVA, 220/132 kV ICT at Sircilla SS (1 No.100MVA PTR charged in Sircilla Dist)


2nd Ckt stringing on existing 220 kV RSS – Nirmal DC/SC line in Adilabad Dist of 140

ckm was commissioned on 30.12.2016 by TSTRANSCO

125 MVAR Bus reactors at Kudgi II, Uravakonda, & Trivandrum was commissioned

during December 2016.

LILO of 400kV Vijayawada-Gazuwaka at Vemagiri was commissioned on 29.12.2016

at 20:55 Hrs by APTRANSCO

Kamuthi ICT V was commissioned on 30.12.2016 at 17:14 Hrs by TANTRANSCO

Ramagundam ICT II which was under prolonged outage since 30.06.2016 was

commissioned on 30.12.2016 at 17:24 Hrs by TSTRANSCO.



System associated with Kudankulam Atomic Power Project (2x1000MW) in Southern

Region” have been put under Commercial Operation w.e.f 00:00 hrs of 23rd

December

2016 in terms of Clause 4 of CERC (Terms and Conditions of Tariff Regulations 2014):

Bunching of Tirunelveli – Edamon section of the Tirunelveli – Muvathapuza

(Cochin) 400 kV quad D/c line initially (and temporarily) at 220 kV with

existing Tirunelvelli – Edamon 400 kV twin D/c line (400 kV line charged at

220kV).

Transmission charges for the above assets are payable with effect from 23rd

December 2016






Conditions of Tariff Regulations 2014):

1 x125 MVAR 400 kV Bus reactor along with associated bay and equipments at

Narendra (New, Kudgi) Substation.

Transmission charges for the above assets are payable with effect from 30th

December 2016





w.e.f 00:00 hrs of 31st



400/220 kV,1 x 500 MVA transformer along with associated bay and equipments

at Madurai Substation

Transmission charges for the above assets are payable with effect from 31st

December 2016





January 2017 in terms of Clause 4 of CERC (Terms and


Replacement of 1 x 50 MVAR bus reactor with 1 x 125 MVAR bus reactor at

400/220 kV Narendra Substation. (The replaced bus reactor shall be maintained

as a regional spare)

Transmission charges for the above assets are payable with effect from 25th

January 2017

60.6 Grid Events/Highlights during January 2017

Wind Mills of 48 MW was added in Andhra Pradesh during December 2016

Wind Mills of 16.8 MW was added in Andhra Pradesh during January 2017.

220 kV D/C line from 400 kV Uravakonda SS to 220 kV Borampalli SS in Ananthapur

district of 134 ckm was commissioned on 07.01.2017 by APTRANSCO.

220 kV SS at Borampalli in Ananthapur district of 100 MVA capacity was


220 kV XLPE UG Cable from Chandrayanagutta SS to Imliban GIS Substation in

Hyderabad district of 9.5 ckm was commissioned on 23.01.2017 by TSTRANSCO.

220/132 kV Imliban GIS SS (PTR – II) in Hyderabad District of 160 MVA capacity


220 kV Vemunuru LIS in Karimnagar Dist of 1 x 50 MVA existing Capacity was

augmented to a capacity of 2 x 50 MVA and was commissioned on 07.01.2017 by

TSTRANSCO.

400 kV S/C Line from Tirunelvelli 400kV SS (Abishekapatty- PGCIL) to Kanarpatty

400 kV SS was commissioned on 09.01.2017 by TANTRANSCO

400/230 kV Kanarpatty SS of 2 x 500 MVA capacity (1000 MVA) was commissioned

on 09.01.2017 at 18:05 hrs by TANTRANSCO

400/110 kV Kanarpatty SS 3 x 200 MVA capacity (600 MVA) was commissioned on at

18:05 hrs 09.01.2017 by TANTRANSCO

4th Autotransformer of 100 MVA capacity at 230/110 kV Palladam was commissioned

on 09.01.2017 by TANTRANSCO

2nd Auto transformer of 80 MVA capacity at 230 /110 kV Nallamanaickenpartty SS was

commissioned on 11.01.2017 by TANTRANSCO

4th Auto transformer of 100 MVA capacity at 230/110 kV at Thiruvalam SS was

commissioned on 23.01.2017 by TANTRANSCO


2nd Auto transformer of 100 MVA capacity at 230/110 kV Aliyar SS was commissioned

on 27.01.2017 by TANTRANSCO

SGPL vide letter dated 20.02.2017 had informed that Trial run of 72 hours full load

operation of Unit II of 660 MW of SGPL had completed and the unit is declared COD

on 21st February 2017.

Capacity building workshop for NPCIL Stations was conducted at MAPS on

23.01.2017.

S3 Bid area was operationalized w.e.f 24.01.2017.

125 MVAR B/R at Trivandrum was commissioned on 24.01.2017 at 16:35 hrs by

PGCIL.

400 kV K V Kota - Suryapet-I (was commissioned on 25.01.2017 at 12:54 hrs by

TSTRANSCO

400 kV K V Kota - Suryapet-II was commissioned on 25.01.2017 at 16:58 hrs by

TSTRANSCO.

SR I, Power grid vide letter dated 31.01.2017 had informed that consequent to the

successful completion of Trial Operation, the following asset under “Substation works

associated with system strengthening in Southern Region for import of power from

Eastern Region” shall be put under Commercial Operation wef 00:00 hrs of 01.02.2017

in terms of clause 4 of CERC (Terms and Conditions of Tariff) Regulations, 2014:

LILO of Gazuwaka-Vijayawada 400 kV S/c line at Vemagiri Pooling Station

along with associated bays.

765/400 kV GIS Pooling Station at Vemagiri with 1 x 1500 MVA 765/400 kV

Transformer.

2 nos. 765 kV bays each at Vemagiri Pooling Station and Srikakulam Pooling

Station

2 nos. 240 MVAR 765 kV Bus Reactor at Vemagiri Pooling Station

1 no. 80 MVAR 400 kV Bus Reactor at Vemagiri Pooling Station

1 no. 240 MVAR switchable line Reactor each at Vemagiri and Srikakulam

Pooling Stations each for both circuits of Srikakulam PS-Vemagiri PS 765 kV

D/c line.

Transmission charges of the above assets are payable wef 01.02.2017.

Powergrid SR I vide letter dated 31.01.2017 had informed the following

Consequent to successful completion of Trial Operation, the following assets

under “Common System associated with East Coast Energy Pvt Limited &

NCC power projects LTOA generation projects in Srikakulam area Part A &

Part C” shall be put under Commercial Operation wef 00:00 hrs of 01.02.2017

in terms of clause 4 of CERC (Terms and Conditions of Tariff) Regulations,

2014.

765/400 kV Sub Station at Srikakulam

765 kV Bay extensions at Angul and Srikakulam Substations along with 2 x 240

MVAR switchable line reactors each at Angul S/S and Srikakulam S/S

1 x 330 MVAR 765 kV Bus Reactor at Srikakulam Sub Station


60.7 Installation of Shunt Capacitors

Progress of installation of capacitors by the constituents during the year

2016-17 is furnished in the Table below:

(Figures in MVAR)

State Requirement

for 2016-17

Installed during the year

2016-17

Andhra Pradesh 549 147.6

Telangana 535.8 0

Karnataka 56.31 0

Kerala 10.00 0

Tamil Nadu 120 19.2

Puducherry 45.8 0

60.8 Demand Variation (Peak Vs Off-peak)

Issue regarding large variation between minimum and maximum demands has been under

the consideration of TCC/SRPC. Issue is also being discussed in the monthly Meetings of

OCC. Following was observed with regard to the period from August 2016 to January

2017:

Descript

ion

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala

Tamil

Nadu Puducherry

Southern

Region

August 2016 Highest 30.66 36.70 36.53 41.42 29.90 56.07 27.66

Date (Day) 31.08.2016

(Wednesday)

02.08.2016

(Tuesday)

02.08.2016

(Tuesday)

08.08.2016

(Monday)

01.08.2016

(Monday)

13.08.2016

(Saturday)

03.08.2016

(Wednesday)

Lowest 13.33 17.39 16.21 31.67 11.31 22.81 7.50

Date (Day) 30.08.2016

(Tuesday)

20.08.2016

(Saturday)

19.08.2016

(Friday)

14.08.2016

(Sunday)

07.08.2016

(Sunday)

28.08.2016

(Sunday)

21.08.2016

(Sunday)

Average 20.55 24.14 24.54 37.26 20.11 31.08 14.87

September 2016 Highest 21.01 38.83 27.73 44.05 29.30 54.79 24.39

Date (Day) 08.09.2016

(Thursday)

18.09.2016

(Sunday)

26.09.2016

(Monday)

03.09.2016

(Saturday)

12.09.2016

(Monday)

28.09.2016

(Wednesday)

26.09.2016

(Monday)

Lowest 11.16 18.33 15.32 30.59 12.14 22.52 9.26

Date (Day) 25.09.2016

(Sunday)

02.09.2016

(Friday)

18.09.2016

(Sunday)

14.09.2016

(Wednesday)

11.09.2016

(Sunday)

25.09.2016

(Sunday)

11.09.2016

(Sunday)

Average 14.96 27.65 20.59 37.76 22.26 31.30 17.66

October 2016 Highest 23.05 34.98 27.24 43.39 31.63 61.66 23.80

Date (Day) 31.10.2016

(Monday)

07.10.2016

(Friday)

12.10.2016

(Wednesday)

31.10.2016

(Monday)

31.10.2016

(Monday)

13.10.2016

(Thursday)

03.10.2016

(Monday)

Lowest 10.50 21.80 9.45 29.49 11.28 16.70 7.43

Date (Day) 11.10.2016

(Tuesday)

11.10.2016

(Tuesday)

27.10.2016

(Thursday)

30.10.2016

(Sunday)

29.10.2016

(Saturday)

15.10.2016

(Saturday)

09.10.2016

(Sunday)

Average 14.94 28.78 18.20 36.58 20.08 29.33 15.85


November 2016 Highest 24.35 40.19 22.33 43.18 30.53 69.69 25.25

Date (Day) 28.11.2016

(Monday)

28.11.2016

(Monday)

28.11.2016

(Monday)

15.11.2016

(Tuesday)

21.11.2016

(Monday)

25.11.2016

(Friday)

28.11.2016

(Monday)

Lowest 11.26 29.58 7.69 31.05 10.34 24.20 10.06

Date (Day) 02.11.2016

(Wednesday)

17.11.2016(

Thursday)

04.11.2016

(Friday)

27.11.2016

(Sunday)

13.11.2016

(Sunday)

13.11.2016

(Sunday)

13.11.2016

(Sunday)

Average 18.45 34.07 16.98 37.33 21.60 32.68 17.63

December 2016 Highest 32.28 41.93 33.58 43.74 44.89 48.99 30.64

Date

(Day)

26.12.2016

(Thursday)

22.12.2016

(Sunday)

12.12.2016

(Thursday)

14.12.2016

(Saturday)

12.12.2016

(Thursday)

12.12.2016

(Thursday)

13.12.2016

(Friday)

Lowest 16.43 32.92 15.35 28.69 16.72 26.59 15.04

Date

(Day)

04.12.2016

(Wednesday)

04.12.2016

(Wednesday)

04.12.2016

(Wednesday)

25.12.2016

(Wednesday)

25.12.2016

(Wednesday)

18.12.2016

(Wednesday)

04.12.2016

(Wednesday)

Average 25.08 37.55 22.13 37.91 25.69 37.27 23.35

January 2017 Highest 35.76 44.49 29.39 41.88 32.26 47.14 29.43

Date

(Day)

20.01.2017

(Friday)

01.01.2017

(Sunday)

27.01.2017

(Friday)

02.01.2017

(Monday)

17.01.2017

(Tuesday)

17.01.2017

(Tuesday)

27.01.2017

(Friday)

Lowest 21.75 31.70 14.82 32.37 19.53 20.57 15.31

Date

(Day)

15.01.2017

(Sunday)

29.01.2017

(Sunday)

11.01.2017

(Wednesday)

08.01.2017

(Sunday)

26.01.2017

(Thursday)

01.01.2017

(Sunday)

27.01.2017

(Friday)

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

60.9 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

Aug 2016 0.00 0.02 6.69 42.41 30.28 20.54 0.06 72.69 50.00

Sep 2016 0.00 0.00 6.74 44.33 30.33 18.58 0.02 74.66 50.00

Oct 2016 0.00 0.00 7.31 46.85 28.58 17.21 0.05 75.43 50.00

Nov 2016 0.00 0.08 10.90 46.76 25.78 16.43 0.05 72.54 49.99

Dec 2016 0.00 0.00 13.24 45.12 24.10 17.44 0.10 69.22 49.99

Jan 2017 0.00 0.00 7.54 43.44 27.73 21.02 0.27 71.17 50.00

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

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

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

requested to kindly adhere to Regulations in this regard.

Issue of caution/violation messages in line with IEGC/Operating Procedure was taken up


by SRPC Secretariat with SRLDC vide letters dated 05.10.2016 and 18.11.2016

(Annexure-LVIII)

60.10 Reasons for demand -supply gap and its variation:

60.10.1 In 4th

Meeting of NPC held on 10.12.2015 (MoM dated 1.1.2016) the following had been

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.


SRPC had stated that the information was being sought by MoP/CEA. Though Surplus

power was available, reasons for deficits such as transmission constraints, distribution

constraints, financial constraints etc needed to be elucidated.

CEA had stated that the data being furnished by SRPC for SR constituents was very

reliable. However during shortage conditions at times, MoP desired exact reason of

shortages like transmission constraint or some other financial reason etc. In certain

states, power was not being supplied due to financial limitations. Vidhyuth Pravaah

App showed power availability in different areas and consumers were raising several

questions in social media to MoP.

60.10.3 For the month of December 2016, the following was noted:

In SRLDC PSP report, load shedding was reported by KPTCL while in the monthly

figure, it was reported as Nil. SRPC letter dated 04.01.2017 in this regard is at

Annexure-LIX.

TANTRANSCO had reported load shedding as Nil though loads had been affected

during Vardha Cyclone. SRPC letter dated 04.01.2017 in this regard is enclosed.

(Annexure-LX).


60.11 Renewable Integration issues

The following issues were deliberated in the TCC:

PCKL stated that weather inputs were very much necessary for RE and demand

forecasting.

KPTCL informed that during this wind season (from May onwards), entire

Karnataka load could be met through wind, solar and CGS drawals. It would be

difficult to manage the LGB.

It was noted that Procedure on Technical Minimum/Compensation for CGS was


likely to be notified shortly. Similar Procedure for intra-state thermal stations may be

required to facilitate RE integration. UD/OD limits were as per the Regulations of

CERC and issues, if any, needed to be taken up appropriately.


61 RELIABLE COMMUNIACTION SCHEME UNDER CENTRAL SECTOR FOR

SOUTHERN REGION

61.1 PGCIL vide letter dated 14.02.2017 (Annexure-LXI) had stated that as desired by Ministry of

Power, DPR for OPGW based Reliable Communication scheme for substations of 132 KV

and above had been prepared by POWERGRID for all the regions. Further, as per directives

of MoP, State Sector Scheme was to be taken up by respective states for their portion and

Central Sector portion by POWERGRID. Accordingly, Fiber Optic connectivity along with

Communication Equipment and associated items from certain stations under Central Sector

scheme are required to be established for data and voice communication to SRLDC for

efficient grid management. OPGW Network of the total of 1,527 Kms (1,084Kms + 443Kms)

has been proposed to be implemented as a part of Reliable Communication Scheme.

Estimated cost of the scheme with OPGW, communication equipment and DCPS (as

required) is 38.17Cr. Tariff for the investment made is to be shared by all constituents in

Southern Region as per CERC notification. The scheme shall become part of existing

Commercial Agreement signed for ULDC Project.


TCC recommended the scheme for approval of SRPC and also for it to become part of

existing Commercial Agreement signed for ULDC project.

61.3 SRPC approved the recommendation of TCC.

62 OPGW LINKS ON LINES CONSIDERING LILO IN FUTURE

62.1 PGCIL vide letter dated 14.02.2017 (refer Annexure-LXI) had stated that for providing

reliable communication from LILO stations, OPGW connectivity is being established on

LILO portion along with transmission line construction. The required OPGW for upcoming

lines had been deliberated in a Meeting taken by Secretary (Power) on 24.07.15 in presence

of CEA and POWERGRID wherein it was decided that upcoming lines may be provided

with OPGW in place of one of the earth-wire. Accordingly, all upcoming lines including

LILO portion is being considered with OPGW. In order to achieve seamless connection of

LILO stations, it is essential to provide OPGW on main line also. Accordingly to ensure

seamless connection of LILO stations it has been proposed to consider OPGW on existing

lines. There are around 20 nos. existing transmission lines which are not having OPGW.

Considering the possibility of LILO of these lines in future, it has been proposed to


implement OPGW on all these lines. Total requirement of OPGW comes out to be 3,879

kms. List of the lines is as per Annexure enclosed. Estimated cost of OPGW, communication

equipment and DCPS (as required) on account of the same comes to 96.97 Cr.


TANTRANSCO had stated that they had requested for inclusion of NCTPS-Almathy line

in the above proposal. PGCIL had agreed to include the above line for OPGW stringing.

KSEBL had enquired about the OPGW stringing in the state lines. PGCIL had clarified

that the state sector OPGW stringing was to be carried out by states with 30% PSDF

funding.

TCC had recommended the proposal and the scheme for approval of SRPC.


63 ALLOCATION OF 6 FIBRES FROM THE 18 FIBRES AVAILABLE AS SPARE

63.1 TANTRANSCO vide letter dated 14.02.2017 (Annexure-LXII) had requested SRPC for

allocation of 6 fibres from the 18 fibres available as per spare, in all F.O links established in

TN through F.O Expansion Project under ULDC scheme. This is subject to condition that

TANTRANSCO shall avail not more than the maximum fibre kms for which eligible for

alternate path provision for their existing F.O links.


TANTRANSCO had stated that PGCIL was laying 5,700 km of OPGW (of 24 fibres)

under ULDC scheme. The cost is being shared by all the constituents. TANTRANSCO

had requested 6 fibres for alternate paths of its network. This provision could be extended

to all the states on fibre km basis.

PGCIL had informed that in most of the FO, there were no spare fibres available. Six

fibres are available for grid management purposes. The balance 18 fibres in the state or

central sector are left to the entities on how to utilize. As for Central sector, 18 fibres are

being leased out to M/s Powertel as per CERC formula which covered issues like sparing

of fibres, cost sharing (50% being shared by M/s Powertel), ROW compensation

(Rs.3000/km) etc. For grid operation purpose, bandwidth on 6 fibres could be given to

the states. M/s Powertel may not take all the 18 fibres in some of the lines but those fibres

are being leased out anywhere.

Keeping in view the non availability of spare fibres in most of FO links and the approved

MoU with M/s Powertel the scheme of allocation the fibres was dropped.


64 FINAL LIST OF OPGW LINKS UNDER FIBRE EXPANSION PROJECT OF

SOUTHERN REGION

64.1 PGCIL vide letter dated 21.02.2017(Annexure-LXIII) had informed that the modified and

final network of 5,735.85 kM OPGW links and 2,287.59 kM of POWERGRID Telecom

network sharing along with final list of links was put up for SRPC approval.


TCC had recommended for approval of the above links



65 OPGW STRINGING ON KPTCL LINES

65.1 PGCIL vide letter dated 21.02.2017 (refer Annexure-LXIII) had referred to the minutes of

31st WRPC/TCC Meeting held on 30

th & 31

st March 2016, where in WRPC recommended for

installation of OPGW 220 kV Xeldom-Ambewadi & 220 kV Ambewadi-Narendra KPTCL

lines as part of Master Communication Plan for OPGW network of Western Region for

extending fibre connectivity to GEDC (Goa Electricity Department) network. Copy of

extracts of WRPC Meeting is enclosed as Annexure-II.

It was proposed that KPTCL consent may be obtained by SRPC for laying OPGW on 220 kV

Xeldom-Ambewadi & 220 kV Ambewadi-Narendra KPTCL lines.


KPTCL agreed for laying on OPGW on 220 kV Xeldom-Ambewadi & 2220 kV

Ambewadi-Narendra lines by PGCIL.


66 REIMBURSEMENT OF SRPC EXPENDITURE

Statement showing net amount payable by Member Utilities of SRPC for the year 2016 -17,

after adjustment of surplus/deficit for the previous period is furnished in Annexure-LXIV.

Members were kindly requested to ensure payment, wherever due.

67 APPOINTMENT OF CONSULTANTS

67.1 MS, SRPC informed about the staff shortage in SRPC Secretariat and stated that approval for

appointment of Consultants would be sought from Chairperson, SRPC in line with the

procedure.

67.2 SRPC agreed for the same.

68 DATE & VENUE OF THE NEXT SRPC MEETING

UPCL kindly agreed to host the 32nd

Meeting of SRPC. Date and venue would be

communicated in due course.

69 CONCLUSION

Chairperson, SRPC stated that issues had been deliberated at length in TCC & SRPC forum.

He thanked all Members for making the Meeting successful.

*******

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