SOUTHERN REGIONAL POWER COMMITTEE of the 33rd Meeting of SRPC held on 17.02.2018 Page 1 Contents 1. INTRODUCTION

Minutes of the 33rd Meeting of SRPC held on 17.02.2018 Page 1

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

2. CONFIRMATION OF THE MINUTES OF THE 32nd MEETING OF SRPC ............................................................. 7

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

4. COAL ISSUES.................................................................................................................................................... 8

5. 400 kV NPS – NELLORE TRANSMISSION LINES LOADING ............................................................................. 15

6. CYBER SECURITY PREPAREDNESS MONITORING .......................................................................................... 16

7. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER ENVIRONMENT

(PROTECTION) AMENDMENT RULES, 2015 .................................................................................................. 17

8. MOP COMMITTEE ON “NHPC TO BECOME GRID STABILISER USING HYDRO POWER” ................................ 19

9. OPTIMUM HARNESSING OF RE IN SOUTHERN REGION ............................................................................... 20

10. COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF RENEWABLE ENERGY

SOURCES ....................................................................................................................................................... 23

11. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE ...................................................... 24

12. MONITORING OF SCHEMES FUNDED FROM PSDF ....................................................................................... 24

13. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY ..................................................................... 25

14. TTC/ATC ........................................................................................................................................................ 28

15 STATUS OF DC IN ISGS .................................................................................................................................. 32

16 FREQUENT TRIPPING OF 765 KV AND 400 KV LINES AND SUSTAINED OPERATION OF ELEMENTS

UNDER HIGH VOLTAGE ................................................................................................................................. 34

17 ISSUES IN RESPECT OF NPCIL ........................................................................................................................ 36

18 UPCOMING TRANSMISSION SYSTEM ........................................................................................................... 42

19 UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH TRANSMISSION NETWORK ............. 54

20 NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ................................................................ 57

21 NEW PROJECTS OF STATE SECTOR & IPP ...................................................................................................... 59

22 REVIEW OF ULDC / SCADA/COMMUNICATION ............................................................................................ 60

23 URTDSM (PMU) PROJECT IN SOUTHERN REGION ........................................................................................ 63

24 EMERGENCY RESTORATION SYSTEM (ERS) .................................................................................................. 63

25 PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR .............................................................. 64

26 NON-AVAILING OF OCC APPROVED SHUTDOWN ......................................................................................... 67

27 STATUS OF PHASE I AND PHASE II OF PROTECTION AUDIT RECOMMENDATIONS ...................................... 69

28 CERTIFICATION OF AVAILABILITY OF TRANSMISSION SYSTEM OF INTER-STATE AND RPC

CERTIFIED FEEDERS ....................................................................................................................................... 70

29 IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION .............................................................................. 70

30 IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT SYSTEM (PMS) FOR

SOUTHERN REGION ...................................................................................................................................... 85


31 COMPLIANCE STATUS OF NEW PROTECTION AUDIT RECOMMENDATIONS ................................................ 85

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

SOUTHERN REGION ...................................................................................................................................... 86

33 PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS ....................................................... 87

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

LVRT AND OTHER PROVISIONS OF CEA/CERC REGULATIONS ...................................................................... 87

35 REVIEW MEETING ON COMPLIANCE OF PCSC RECOMMENDATIONS .......................................................... 89

36 COMMERCIAL COMMITTEE ISSUES .............................................................................................................. 92

37 AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM........................................................................... 96

38 GRID OPERATION .......................................................................................................................................... 97

39 REIMBURSEMENT OF SRPC EXPENDITURE ................................................................................................. 102

40 STATE-WISE ALLOCATION OF 540 MW POWER FROM RGPPL TO RAILWAYS ............................................ 102

41 REPORT OF POLLUTION MAPPING OF SR BY CPRI ...................................................................................... 103

42 OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE .................................................................. 103

43 DEFAULT IN PAYMENT OF OUTSTANDING DUES BY BENEFICIARIES .......................................................... 104

44 INCLUSION OF DRAWAL OF MAHE IN REA ................................................................................................. 104

45 UNREQUISTIONED SURPLUS (URS) ............................................................................................................. 105

46 RSD & TECHNICAL MINIMUM ..................................................................................................................... 106

47 NON-ADHERENCE TO THE MAINTENANCE SCHEDULE SPECIFIC CASE OF OVERHAULING OF

TALCHER STAGE II UNITS ............................................................................................................................ 106

48 URS ALLOCATION TO NON-BENEFICIARY ................................................................................................... 107

49 OUTAGE CATEGORISATION UNDER DEEMED AVAILABILITY ...................................................................... 107

50 TECHNICAL COMMITTEE FOR IMPLEMENTATION OF FRAMEWORK ON RENEWABLE AT STATE

LEVEL -FOR .................................................................................................................................................. 107

51 TECHNICAL COMMITTEE CONSTITUTED BY CEA ......................................................................................... 108

52 COMMITTEE FOR PROPOSING METHODS FOR INTEGRATED OPERATIONS OF RESOURCES IN A

RIVER IN THE COUNTRY .............................................................................................................................. 110

53 INCLUSION OF DRAWAL OF KARAIKAL REGION OF UT OF PUDUCHERRY IN REA ...................................... 110

54 HIGH DECLARATION OF DC FROM NTPC KUDGI THERMAL POWER PLANT FROM 01.01.2018

ONWARDS ................................................................................................................................................... 111

55 ROSTER FOR HOSTING THE SRPC MEETINGS .............................................................................................. 113

56 VOTE OF THANKS ........................................................................................................................................ 114

57 DATE & VENUE OF THE NEXT MEETING OF SRPC ....................................................................................... 114


SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

MINUTES OF THE 33rd

MEETING OF SRPC HELD ON 17th

FEBRUARY 2018 AT

PUDUCHERRY

1. INTRODUCTION

1.1 The 33rd

Meeting of the Southern Regional Power Committee (SRPC) was held on 17th

February 2018 at Puducherry. The list of participants is given at Annexure-I.

1.2 NLCIL/NTPL extended a hearty welcome to all delegates to the 33rd

SRPC Meeting.

NLCIL/NTPL also thanked Southern Regional Power Committee for bestowing this

opportunity to host the 32nd

TCC & 33rd

SRPC Meetings.

1.3 Shri V Thangapandian, Director (Power), NLCIL on behalf of NLCIL & NTPL

welcomed eminent & distinguished dignitaries to the SRPC Meeting. He stated that

SRPC Meetings were highly constructive and beneficial. He thanked Chairperson, SRPC

& Member Secretary for providing this opportunity to NLCIL/NTPL to host the

Meeting. He specially greeted Shri D Prabhakar Rao and stated that it was indeed a great

honour to have him as Chairperson of SRPC. He informed the gathering that Shri D

Prabhakar Rao was the person who had taken power deficit as a challenge and

transformed Telangana into a power surplus state, while ensuring 24 hours of power

supply to farmers and rural areas. This was indeed a marvelous achievement for

Telangana in such a short duration of time and a lot could be learnt from him. He also

stated that SRPC under the able guidance of Shri S R Bhat, Member Secretary was

achieving a number of milestones. He welcomed Shri Dinesh Paruchuri, JMD,

APTRANSCO, Shri T H M Kumar, MD, PCKL, Shri N S Pillai, CMD, KSEBL, Shri R

P Sasmal, Director (O), PGCIL, Shri Satish Jindal, COO, JSWEL, Shri G Narsing Rao,

Director, TSTRANSCO, Shri S. Shanmugam, MD TANTRANSCO, Shri T Senthilvelan,

Director (Transmission Projects), TANTRANSCO, Ms A Axilium Jayamary, Director

(O), TANTRANSCO, Ms M A Helen, Director (D), TANGEDCO, Shri S M Zafrulla,

MD, CEPL , Shri G. Anbunesan, GM, SRLDC, CEOs/Directors, Members from NTPC,

NTECL, IPPs, Members of Transmission & Distribution Companies and distinguished

guests to the Meeting. Director (Power), NLCIL mentioned that management of SR

power system by the constituents was highly laudable. He also stated that the

functioning of SRPC is simply outstanding.

Director (Power) briefed about NLCIL and its various activities. NLCIL had

commissioned 2 x 250 MW lignite fired CFBC boilers at Neyveli (TS II Expansion)

which is first of its kind in India. With 140 MW of solar and 51 MW of wind, NLCIL


had also ventured into renewables. NLCIL are also implementing 995 MW of solar plant

at various sites in TN. NLC is also constructing a replacement plant (NNTPS) of 2 x 500

MW in place of TS-I (600 MW) which is expected during June/July 2018. Construction

activities of this plant are nearing completion while commissioning activities had picked

up. With active help of SRPC, SRLDC & TANGEDCO, NNTPS was able to obtain start

up power in time for this plant and he thanked all for the same. NLCIL is also in the

process of implementing a 2 x 660 MW plant at Neyveli and 3 x 800 MW coal based

plant at Talabira (Odisha) which is linked with 20 MTPA mine at Talabira. The fuel is

likely to be cheap since it is a linked coal mine. Odisha Government has accorded

clearance for land, water etc, MOEF clearance had been received and pre project

activities were progressing well. During FY 2017-18 (till Jan-2018) NLCIL had

generated 17,184 MU and exported 14,422 MU of energy against generation of 17,251

MU and export of 14,503 MU during the same period in FY 2016-17. During the period

till Jan-18 in FY 17-18, NTPL had generated 4,428 MU and exported 4,108 MU. PLF of

NTPL was around 60 %, which was mainly due to coal availability issues during

monsoon. ECL/MCL had provided more than the linkage quantity for which NTPL was

thankful. The issue regarding operational flexibility and compliance of revised Technical

Minimum as per CERC Regulations was being faced by NLCIL. Hence,to overcome that

NLCIL had resorted to URS power trading. He hoped that the Meeting would pave way

for addressing various pending issues and also look into the trading/technical minimum

related issues. He once again thanked all Members for their gracious presence and said

that the forum would benefit from their valuable inputs.

1.4 NLCIL presented a short film in which the following was highlighted:

Twin objective of mining and power generation which produces economic power

to all.

A Navratna CPSU under Ministry of Coal and pioneer provider of India‟s energy

security.

28.5 MTPA lignite mine at Neyveli & 2.1 MTPA lignite mine at Barsingsar.

Operates thermal power stations of 2,990 MW at Neyveli, 250 MW at Barsingsar

& 1,000 MW NTPL station at Tuticorin - a JV between NLC & TANGEDCO.

NNTPS of 1,000 MW is a replacement plant of NLC TS-I which had served its

useful life.

NLCIL is in the process of setting up coal mines of 31 MTPA in Odisha &

Jharkhand, coal based power plants of 6,000 MW in UP & Odisha, 4,200 MW of

wind & solar to fulfill the vision of attaining 21,000 MW installed capacity by the

year 2025.


1.5 Shri D Prabhakar Rao, Chairperson, SRPC & CMD, TSTRANSCO extended warm

greetings to all. On behalf of SRPC, he also extended sincere thanks to CMD, NLCIL

and his team for hosting this SRPC Meeting in such a nice environment. He also

conveyed sincere thanks to all participants from different states and utilities for making it

convenient to attend the SRPC Meeting. Southern Region has been on the forefront in

maintaining grid discipline and during last NPC Meeting held at Indore, Chairperson;

CEA had appreciated constituents of SRPC for taking lead role in scrupulous

implementation of CERC / CEA Regulations and MoP guidelines. One main issue was

with regard to maintenance of adequate coal stock in thermal plants, keeping in view

energy security concerns. In order to reduce emissions, GoI has a vision to replace petrol

/ diesel vehicles with electric vehicles. Electric vehicle industry is picking up in India

and the target is replacement of 100 % public transport and 40 % private mobility with

electric vehicles by 2030. There was thus urgent need to create charging infrastructure

with reliability, which would be a major factor for growth of electric vehicle industry in

India. In an effort to enhance energy security and also minimize adverse effect to

environment from road transport vehicles, all states of Southern Region are to be geared

up to supply bulk power to charging agencies. Andhra Pradesh had already taken lead

role in creating a separate consumer category while Telangana in consultation with State

Electricity Regulatory Commission was also on the way, Cyber Security in Power sector

was also very important in view of increasing incidents of cyber-attacks and threat to

integrated grid operation. All utilities need to monitor action taken with regard to

identification of critical infrastructure, preparedness of Crisis Management Plan (CMP)

and carrying out Mock Drill exercises. In this background, CEA (IT) Division was to

make a Presentation, which indeed is a welcome initiative. Guidelines and

comprehensive action plan by CEA would be extremely helpful for the utilities.

Regarding Telangana power scenario, he thanked Director (Power), NLCIL for the kind

words expressed. Power sector in Telangana is witnessing quality, reliable and 24 hours

free power to agricultural sector from 01st January 2018. This free power is being supplied

successfully to all pump sets in Telangana. Telangana being the new 29th

state had met a

peak demand of 9,622 MW on 16th

February 2018. It was anticipated that the state may

meet around 11,000 MW of demand in coming period. The transmission and distribution

system in the state is geared up to meet 17,000 MW. In generation front, the state sector is

planning to commission 800 MW (first time) at Kothagudem with the active support of

OEM and engineering staff by next month. In addition to that, 1,080 MW (4 x 270 MW) is

coming up at Manuguru with 2 units planned by end of this year and balance 2 units by


February/March next year. Another Ultra Power Project of 5 x 800 MW at Damaracherla

is also moving ahead and had been awarded to M/s BHEL on EPC basis. The project was

held up on account of environmental clearances and may come up in another 3-4 years.

In addition to that NTPC is coming up with 2 x 800 MW power plant at Ramagundam, of

which one unit is expected to be commissioned by end of 2019 and second unit by

March/April 2020. The total capacity in Telangana which is now around 15,120 MW could

be around 28,000 MW in the coming 3-4 years. Telangana is having two major hydro

projects, both of which are reversible. At Srisailam LB, there are 6 x 150 MW units (900

MW) which are being used in pump mode. 25 TMC of water had been pumped back this

year. At Srisailam RB, there are 7 units of 110 MW which are with Andhra Pradesh.

N‟Sagar is also reversible and in a major development, TSGENCO had made 7 units of

100.8 MW each ready for use in pump mode, as per grid requirement. 3 units are being

used in pump mode while others would be made operational shortly. In the context of large

scale renewable integration, this availability of pump mode is highly beneficial for optimal

load generation balance. Telangana is also having 3,200 MW of installed capacity of Solar

which was quite large. Another 800 MW of Solar is expected by 2019-20. In Telangana,

Solar is being commissioned as per distributed generation model, thereby ensuring optimal

utilization of transmission/distribution assets and better grid management. With active

support of the Government and with sincere efforts of PGCIL interregional link between

NEW & SR (765 kV Wardha-Nizamabad D/C) had been commissioned and Telangana

was able to draw about 1,000 MW power from Chattisgarh. He thanked PGCIL for their

wonderful efforts in this regard.

Chairperson, SRPC requested all delegates to express their views and opinion on the

agenda points which would help in taking proactive decisions in the interest of SR grid.

Southern Region continues to play a lead role in power sector in the country. He

appreciated and placed on record the sincere efforts made by SRPC Secretariat under the

able leadership of Shri S R Bhat, Member Secretary.

1.6 Shri S R Bhat, Member Secretary, SRPC thanked Chairperson, SRPC for inspiring the

forum and also for providing valuable guidance in many matters. He stated that in his

tenure, a number of initiatives had been taken up with Chairperson, SRPC providing

excellent leadership. He thanked Director (P), NLC, CGM (T), NLC and the NLCIL

team for the excellent arrangement made for conduct of the Meeting.

SRPC welcomed the following new Members to the forum:

Shri M M Nayak, CMD, APSPDCL, Tirupati

Shri N S Pillai, CMD, KSEB Ltd., Thiruvananthapuram

Shri Debasis Sarkar, CEO, NTECL, Vallur

Shri Jayadeb Nanda, COO (O & M), UPCL

Shri Vipul Tuli, Managing Director, TPCIL, Nellore

Shri Ashok K Puri, Managing Director, HNPCL

Shri Kumaran P, Director (Distribution and IT), KSEBL


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

Members:

Shri H Y Dora, CMD, APSPDCL, Tirupati

Dr K Ellangovan, CMD, KSEB Ltd., Thiruvananthapuram

Shri C V Anand, CEO, NTECL, Vallur

Shri A Mohan Nargund, CEO, TPCIL, Nellore

Shri N Venugopal, Director (Distribution and Safety), KSEBL

SRPC also placed on record the outstanding contribution of Shri R P Sasmal, Director (O),

PGCIL in the SRPC forum. Shri R P Sasmal would be demitting his office by the month

end. Under his excellent leadership, a number of elements had been added for the benefit

of SR constituents at quite a rapid pace. Member Secretary, SRPC also informed that

CERC staff was visiting SRPC, Bengaluru on 22nd

February 2018 to have interactions with

SR utilities on „Terms and Conditions of Tariff, 2019-24‟. He requested

STUs/Discoms/generators to be kindly present and share their views/concerns/feedback.

SRPC also welcomed Shri Rajesh Mishra, HOD (M&S), MCL and Shri R Raghuraman,

DCOM/Freight, Southern Railways who were Special Invitees to the Meeting. Their inputs

would be highly useful to the forum in the backdrop of prevailing coal supply / coal

transport scenario.

1.7 The Agenda was taken up for deliberations.

2. CONFIRMATION OF THE MINUTES OF THE 32nd

MEETING OF SRPC

2.1 Minutes of the 32nd

SRPC Meeting held on 22nd

August 2017 at Thiruvananthapuram

had been circulated vide letter dated 23rd

October 2017.

2.2 Minutes of the Meeting was confirmed.

3. MEMBERSHIP TO RPC

3.1 Ministry of Power vide Resolution dated 21.12.2017 (Annexure-II) had amended

(added) the following clause after clause (vii) of paragraph 3 of the Resolution dated

25.05.2005 namely:-

“(vii a) A representative each of every Nodal Agency appointed by the Government of

India for coordination cross-border power transactions with the countries having

electrical inter-connection with the region”.

SRPC noted that a Representative each of every Nodal Agency appointed by the GoI

for coordination of cross-border power transactions with countries having electrical

inter-connection with SR would be a Member of SRPC. This would be applicable, as

and when, Southern Region is electrically interconnected with other country and the

Nodal Agency is nominated by GoI.


3.2 CEA vide letter dated 03rd

August 2017 had communicated Membership of JSW Power

Trading as Trader Representative in SRPC for 2017-18. In the 32nd

Meeting of SRPC,

COO (Trading), JSWEL had expressed concern over nomination being communicated in

August, since objective of representation had been lost. It had been suggested that CEA

may kindly communicate Membership during March / April each year so that concerned

Trader is associated with respective RPC for the entire year. It had been agreed that this

matter be brought to the kind attention of CEA. MS, SRPC vide letter dated 29.08.2017

(Annexure-III) had taken up this matter with CEA.

TCC deliberations

TCC had opined that since Membership had been communicated during August

2017 (mid 2017-18), JSW Power Trading be exempt from SRPC Membership for

the FY 2017-18.

MS, SRPC had informed that details in this regard for the year 2018-19 had already

been communicated to GM Division, CEA.

SRPC deliberations

SRPC exempted JSW Power Trading from SRPC Membership for the FY 2017-18.

3.3 Managing Director, TANTRANSCO vide letter dated 29.08.2017 (Annexure-IV) had

proposed that in addition to existing Members to SRPC from Tamil Nadu, the nomination

of Director (Transmission Projects) TANTRANSCO may also be included.

TCC deliberations

TCC had noted that there had been some exceptions earlier and hence had

recommended for Membership of Director (Transmission Projects),

TANTRANSCO to SRPC from the financial year 2018-19.

SRPC deliberations

SRPC approved the Membership of Director (Transmission Projects),

TANTRANSCO to SRPC from the FY 2018-19.

4. COAL ISSUES

4.1 Number of thermal power stations in the Region had faced critical coal stock situation in

the past few months. Chairperson, SRPC vide letters dated 25th

September 2017 and 13th

November 2017 (Annexure-V) had taken up the issue regarding critical coal stock and

availability of sufficient rakes with Ministry of Power. SRPC vide letter dated 22nd

November 2017 (Annexure-VI) had raised energy security concerns with Hon‟ble

CERC and requested that the matter regarding maintenance of low coal stock by CGS

station whose tariff is approved by Hon‟ble Commission may kindly be examined. A

Special Meeting was also convened at NTPC, Secunderabad on 21st December 2017 to

discuss matters relating to coal supply including diversion (MOM available at SRPC


website). The projected availability by most of the generators was considering adequate

coal stock. However lesser generation availability (DC) on account of fuel supply issues

was affecting LGB of the states. It also affected procurement of power which is based on

the LGB. As agreed in the Secunderabad Meeting, Chairperson, SRPC vide letter dated

28th

December 2017 (Annexure-VII) had taken up the issue regarding „Consent of

original beneficiaries‟ for diversion of coal with Chairperson, CEA.

4.2 NTPL vide letter dated 23.12.2017 had intimated that for operating both the units at 85

% PLF, 4.735 MTPA of coal was required and had requested to kindly take up the issue

with CEA for directing both MCL and ECL to enhance FSA quantity for NTPL.

Subsequently, SRPC vide letter dated 29th

December 2017 (Annexure-VIII) had taken

up this issue with Fuel Management Division, CEA. Reply of CEA dated 03rd

January

2018 is given at Annexure-IX.

4.3 MS SRPC vide letter dated 17th

October 2017 (Annexure-X) had also communicated

concerns expressed by generators in the methodology adopted by CEA in assessment of

daily coal stock position. On these issues raised by SRPC, Fuel Management Division,

CEA vide reply dated 20th

November 2017 (Annexure-XI) had informed the following:

There are no Specific coal consumption (SPC) norms specified by FM Division,

CEA.

As per new methodology issued on 08.11.2017, revised criteria for Critical / Super

critical coal stocks for TPPs would be as under:

Criticality Plants Criteria

Critical stock Pit-head Plants Coal stock less than 5 days

Non-Pit head Plants Coal stock less than 7 days

Non-Pit-head Plant

(More than 1,500 kms)

Coal stock less than 9 days

Super-critical stock Pit-head Plants Coal stock less than 3 days

Non-Pit head Plants Coal stock less than 4 days

Non-Pit-head Plant

(More than 1,500 kms)

Coal stock less than 5 days

Daily coal requirement of a Plant would be based on average coal consumption of

previous 7 days (rolling average) subject to a minimum PLF of 55 %.

4.4 There was need to maintain adequate coal stock in thermal stations, on account of energy

security concerns.

4.5 The following had been noted in the TCC Meeting:

MS, SRPC had appraised TCC about the issues in coal transport and supply. CERC

Staff was conducting a preliminary Meeting on 22nd

February 2018 in SRPC,


Bengaluru to obtain inputs for Terms and Conditions of Tariff Regulations 2019-24.

These issues could be further highlighted in that Meeting. All Discoms and

stakeholders were requested to attend that Meeting and present their case. Coal stock

position as on date was comfortable in respect of generators in Telangana and Tamil

Nadu while situation in KPCL, APGENCO and Simhadri-NTPC stations was not very

comfortable. To sort out these issues Railways and MCL had been invited as Special

Invitees to the SRPC Meeting.

APGENCO had stated that the problem persisted with Railways and sufficient number

of rakes were not being allocated.

CE (IT), CEA had informed that CEA and NTPC, with active help of Railways and

Ministry of Coal are developing an IT application which would help in monitoring of

coal stock available at each Railway siding, with daily receipts and dispatch of coal,

rake allocation for coal supply to generating stations. This along with stock,

consumption and receipt of coal at generating station as available in NPP Portal,

would help in effective monitoring of coal supply. This would help ensure that coal

movement is monitored from source to consumption.

Director (GM), CEA had informed that the coal diversion matter had been examined

by CEA. It had been clarified that „Consent of original beneficiaries‟ would be

required for the purpose of diversion (a formal reply in this regard would be

communicated).

CEO, NTECL had expressed concern that ACQ for NTECL (6.24 MMT) was not

sufficient and requested its enhancement (8.863 MMT equivalent to 85% PLF). This

issue regarding specific coal consumption and total lead time had also been taken up

with CEA (refer Annexure-X). The issued norms dated 15.01.2015 on coal

consumption is given at Annexure-XII.

CEO, NTPL had stated that they require around 4.7 MTPA (at 85 % PLF) to run at

full load while ACQ was only for 2.9 MTPA (MCL: 2.6 MTPA, ECL: 0.3 MTPA).

Though coal availability of NTPL was less than 7 days, it had not been categorized

under 'Critical/Super Critical Stock' position status by CEA since coal supply to NTPL

had crossed 75 % of ACQ. This was the trigger level for post -2009 thermal power

plants as per clause 2C of CEA Fuel Management Division Revised Guidelines for

Preparing Daily Coal Report.

It was noted that the NTPL matter had been taken up with Fuel Management Division,

CEA and they had referred it to TPP&D Division for further action. Coal adequacy

issues were being viewed seriously by Hon‟ble Commission and CERC staff had also

reportedly taken up this matter with individual generators.

TSTRANSCO and TANTRANSCO had requested generators to maximize the

availability/generation up to May 2018.

NTPC had informed that dedicated officials had been posted at Talcher &

Bhubaneswar to coordinate coal supply and rake movement/allotment. Presently, the

issue was with regard to rake availability/movement.


SRPC deliberations

4.6 MS, SRPC informed that all inputs received in respect of coal supply and coal transport

from GENCOs had been compiled and duly communicated to MCL & Railways.

4.7 The following was noted in respect of Railways:

APGENCO

APGENCO had informed that during the period October 2017 to December 2017,

realization was around 74% and 78% at Vijayawada TPS and Rayalaseema TPS. It

had expressed concern that for the month of January 2018 (upto 18th

) only 25 rakes

were loaded against the 66 rakes sanctioned at Talcher siding, 52 rakes were loaded

against 92 rakes sanctioned at Ib siding and only 03 rakes were loaded against

sanctioned 52 rakes at Balram siding. More than 96,000 MT of washed coal was lying

at M/s Spectrum Washery.

APGENCO had requested for minimum 2 rakes/day at Balram siding. Moreover,

sufficient rakes were required at Talcher (3 rakes/day) and Ib (5 rakes/day) sidings

to improve the coal at Vijayawada TPS and Rayalaseema TPS which was less than 5

days on sustained basis. Unit 6 at Rayalaseema (Stage IV) is also in advanced stage

of commissioning and additional rakes were required.

Shortfall in rakes per day for APGENCO power plants was as follows:

a) Dr NTTPS – 1.75 rakes/day

b) RTTP Stages I, II & III – 0.36 rakes/day

For the upcoming unit of RTPP Stage IV, SLC had sanctioned linkage. Additional 2

rakes/day is required for movement of raw coal from MCL for this purpose.

KPCL

From MCL, 218 rakes provided by Railways against programmed of 291 (60% of MSQ

through ARR). Realization is around 75% for the FY 2017-18 (upto Dec 2017). In

respect of WCL, 206 rakes were provided against FSA quantity of 437 rakes for the FY

2017-18 (upto Dec 2017). This was because Central Railways (CR) was not providing

adequate empty rakes. 7 rakes/per day is required from SCCL but SCR had supplied

less rakes due to non-availability of adequate BOXN rakes. Concerned Zonal Railways

do not have adequate strength of „Valid‟ rakes, which is affecting movement.

KPCL had informed that entire supply of SCCL, portion of WCL supply & portion

of MCL supply through RSR via Krishnapatnam as well as imported coal are to be

transported by SCR. Around 18 rakes/day would be required by KPCL for FY 2018-

19. Additionally around 2-3 rakes were required for fly ash movement. KPCL had

requested to ensure adequate availability of valid rakes for movement of allocated

coal through ARR.

TANGEDCO

Coal is transferred from Talcher coal fields to Paradip port and then to TANGEDCO

stations either through Rail cum Sea route or Rail-Sea-Rail route. During January

2018, 226 rakes were dispatched by Railways against sanctioned 337 rakes.

TANGEDCO requested for adequate rakes allocation/loading.


NTPC Kudgi

Strengthening of Bhima River bridge by SWR as movement of CC+8 rakes ruled out.

Shortage of BOXN wagons in SCR. There was congestion in Gadag route and shortage

of SWR crew and locos for rakes via Gadag and Hotgi. There was shortage of Banker

for rakes via Hotgi due to up gradient. Further, there was shortage of premium rakes at

Bandag siding (BNDG) for Pakri-Barwadih.

NTPC Simhadri

Against the requirement of 12 rakes/day (MCL-Talcher, MCL-Ib, ECL and SCCL)

Simhadri only around 6-7 rakes/day. Physical coal stock was in the range of 0-3 days

on sustained basis since last few months. Unit was also taken out due to critical coal

stock. Rake realization from ECR was less. The logistic constraints between

Sambalpur-Rayagada and the congestion between Vizainagaram and Vizag were also

highlighted.

NTPC Simhadri had requested railway to address these issues.

NTECL Vallur

NTECL had pointed that during the period July 2017 to December 2017 against the

offer of 746 rakes (from MCL-Talcher, MCL-Ib, MCL-Dharma, ECL and CCL) 729

rakes were allocated while 637 rakes were actually loaded.

Unit-III is likely to come on bards shortly and thus maximum rake allocation /

loading is required.

NTPL Tuticorin

NTPL had pointed out that during the period from April 2017 to December 2017,

against 330 rakes requested to Railways, only 257 rakes were actually allotted which is

around 78%.

NTPL had requested for maximum rake allocation / loading as they were short of

the target Plant Availability Factor.

MCL

Availability of Box N rakes for maximizing long distance linkage power plants to be

improved. Presently, Box N rakes are not sufficient with Zonal Railways. The issue of

congestion in ECO Railways, for rakes going to Paradip and through Sambalpur –

Titlagarh route affecting rake materialization for plants location in Southern Region.

Also BOB rakes need to be allowed over long distance for power plants such as

Simhadri and other plants with BOB rakes unloading facilities.

4.8 Director (T), APGENCO stated that there were no coal supply issues in respect of MCL.

Problem persisted for Rayalseema TPS with regard to availability of sufficient rakes

(BOXN) on account of long distance involved. Adequate rakes for Krishnapattnam,

Rayalaseema Stage-IV (600 MW) and at Spectrum Washery were also required. 5

rakes/day at Ib and 3 rakes/day at Talcher were required to improve the coal stock at

Rayalaseema & Vijayawada stations.


4.9 Technical Director, KPCL reiterated the Railway issues being faced by KPCL and

requested for concerted support from Railways in this regard. Around 18 rakes/day would

be required during the year 2018-19.

4.10 Regional ED, NTPC stated that track congestion issue needs to be addressed to improve

the coal supply to NTPC stations specifically at Simhadri. For Simhadri, only 50 %

loading had been possible on account of less rake realization. Arranging additional coal

would not serve any purpose, in case the same cannot be transported.

4.11 CEO, NTECL expressed concern on the ACQ for NTECL (6.24 MMT) which was not

sufficient and requested for enhancement of ACQ (8.863 MMT equivalent to 85% PLF).

Director (O) had taken up the issue with JS (Thermal), MoP regarding enhancement of

ACQ. He requested Railways / MCL/CCL to ensure adequate supply of coal to the station.

Since route was Rail-Sea, the transit time was slightly higher at 7-8 days from mine to

station. NTECL was able to manage presently due to forced outage of Unit-3. However,

with all three units on bars, the present supply of 3-4 rakes would not be sufficient.

4.12 In respect of NTPL, Director (P), NLC stated that ACQ under existing FSA with ECL &

MCL is only sufficient to operate the power plant for about 22 days/month (73.33%). For

operating both units at 85 % PLF, 4.735 MTPA of coal is required. NTPL is not being

flagged as critical / super critical even when coal stock is less than 3 days. „The coal

supply exceeded the trigger level‟ is the reason being cited by CEA for this. Against

request of 330 rakes, only 257 rakes were actually allotted for the period from April 2017

to December 2017. As per new methodology for monitoring coal stock position, the

criteria for flagging critical and super critical status for non-pit head station is coal less

than 7 days and 4 days respectively. As far as NTPL is concerned, which is situated at the

farthest point from coal supply point, it normally takes more than 15 days through Rail

cum Sea mode, since ship has to sail around Sri Lanka. Hence, it is requested to consider

the criteria for flagging critical / super critical status for NTPL as 15 days and 7 days

respectively.

4.13 DCOM/Freight, Southern Railways stated that concerns of SR generators would be duly

communicated to the Management. He assured that 2 rakes/day at Balram Siding would be

ensured for APGENCO.

4.14 Chairperson, SRPC observed that there needs to be some firm commitment/specific action

plan from Railways.

4.15 HOD (M&S), MCL stated that MCL is endeavoring to maximize supply to SR generators

through sustained monitoring. The Sub Committee with Members from MoC, MoR, MoP,

CIL, CEA etc review coal stock on a weekly basis and sometimes on bi-weekly basis.

MCL is continuously taking up the transport related issues with Railways. Availability of

BOXN rakes (in ECR and ECOR) for long distance linkage power plants is to be

improved. Presently, BOXN rakes are not sufficiently available with Zonal Railways. To


Paradip port, BOBR rakes were being supplied, and Gencos may need to avail RSR route

also instead of All Rail Route to reduce congestion. There had been no shortfall in offer by

MCL while problem was mainly with regard to availability of rakes by Railways. Certain

Inter Zonal Railway issues and congestion in certain sections were also highlighted. There

was congestion in ECO Railways, for rakes going to Paradip and through Sambalpur –

Titlagarh route affecting rake materialization for plants located in Southern Region. Also

BOB rakes need to be allowed over long distance for power plants such as Simhadri and

other plants with BOB rakes unloading facilities. In case Railways could offer 56

rakes/day for power sector, the entire requirement could be met. He also requested Gencos

for clearing of the dues to MCL in a timely manner. Specific issues of respective Gencos

are given below:

APGENCO: Vijayawada lifting coal through both Rail and Road mode while

Rayalaseema is lifting through rail mode only. Lately, Vijayawada not lifting coal

through road mode citing less evacuation of washed coal and requesting more raw coal

through rail mode.

APPDCL (Damodaran Sanjeeviah): APPDCL should modify its logistic arrangements

through washery for faster evacuation of washed coal. The coal is being lifted through

road mode.

TPCIL: The programme is not being placed each month for lifting coal from Ib. The

coal stock at Paradip port is not being evacuated faster. Materialization remained poor

on account of less supply of rakes by Railways.

HNPCL: There are unloading constraints as it is being unloaded in public siding and

later being transported to the consumption point.

TANGEDCO: Stations of TANGEDCO are offered coal from both Talcher and Ib. The

dispatch from Talcher had increased since Railways had augmented rake supply.

Dispatch materialization from Ib field had been higher although TANGEDCO is

reluctant to increase its supply from Ib.

NTECL: NTECL is being offered coal both from Talcher and Ib. Materialization from

Talcher remained less on account of lesser number of empty rake supply.

NTPL: NTPL has entered into an agreement with private Washery of operator for

taking washed coal. Subsequently, MCL had leased Deulbera siding for further

transport of washed coal. However, there is scope for enhanced materialization of

washed coal if adequate arrangement for road lifting is made. MCL is regularly

supplying additional raw coal through rail mode to tide over the immediate stock crisis.

Raichur-KPCL: Raichur is lifting coal from Talcher and Ib through both ARR and RSR

route (via Paradip port). However, KPCL has started programme from Ib only since

October 2017. Based on the request of KPCL, additional quantity of coal is being

offered to sustain generation and stock buildup. Prorata materialization from MCL was

103 % during 2017-18 (upto Feb).

Simhadri-NTPC: Simhadri is being offered both from Talcher and Ib. Earlier rakes

were diverted which lead to low stock situation at the station. Less rakes supply by


Railways had also lead to lower materialization.

Coal supply status for Southern Region power houses for the period April 2017 to

January 2018 and dispatch plan for February and March 2018 of MCL is given at

Annexure-XIII

4.16 After deliberations, it was agreed that Chairperson, SRPC may be kindly requested to

take up the matter with Chairman, Railway Board, highlighting problems being faced by

SR coal based thermal generators.

5. 400 kV NPS – NELLORE TRANSMISSION LINES LOADING

5.1 In the 41st

Meeting of SCPSPSR, the following had been noted, „CTU informed that 400kV

Nellore PS Nellore D/C lines have to be opened to control short circuit level of Nellore SS.

CTU recommended opening both the lines. Also informed that 765kV Nellore PS-Kurnool

D/C line and 400kV Nellore PS-Gooty D/C line is sufficient for evacuation of Power from

Nellore Complex‟.

5.2 MEL/SEL vide letters dated 04.11.2017 and 06.11.2017 (Annexure-XIV) had raised

certain issues regarding overloading / tripping of NPS – Nellore Loop Out segment and

non-implementation of decision of isolating the segment. Issue of maintenance

responsibility had also been raised. This issue was deliberated in the 137th

Meeting of

OCC held on 10.11.2017. (Relevant extract is enclosed at Annexure-XV). NLDC vide

letter dated 01.12.2017 (Annexure-XVI) had taken up this issue with CTU and requested

that these aspects be examined and solution evolved in the interest of secure grid

operation. CTU vide letter dated 15.12.2017 (Annexure-XVII) had replied to POSOCO‟s

letter and stated that in the event of outage of both circuits of Nellore PS - Nellore 400 kV

D/C, loadings on remaining outlet from Nellore PS are generally in order with full dispatch

of LTA quantum (3,436 MW) at Nellore complex. Accordingly, it had been proposed that

Nellore PS - Nellore 400 kV D/C line be kept in service under normal conditions.

However, in the event of outage of one circuit, the other circuit may also be opened.

5.3 In the OCC forum, SEL & MEL had been requested to take up this matter with

NLDC/CTU regarding SPS implementation to trip surviving line, in case other line trips

while line loading is beyond specified limits. SR-I had stated that maintenance of the LO

portion of Nellore – NPS line was to be carried out by SEL/MEL. Also, there had been a

grid incident in Nellore S/S on 12th

January 2018 on account of CVT failure.

5.4 After deliberations, TCC had concluded the following:

TCC recommended for SPS, during tripping of one of the lines of NPS-Nellore. SPS

logic would be finalized in consultation with SRLDC, PGCIL, SEL & MEL and SRPC

Secretariat.

During any outage of this interconnector, system operator would take appropriate

decision, regarding curtailment, if any, of interregional ATC or curtailment of NPS

connected generators etc as per provisions of extant Regulations.


CTU had clarified that maintenance of the LO portion would continue to be carried out

by MEL & SEL.

TCC recommended that provision of third ICT at NPS could be planned/studied as a

long-term measure. Other options could also be looked into by CTU as discussed in

earlier Meetings / suggested by POSOCO.

5.5 SRPC noted the above.

6. CYBER SECURITY PREPAREDNESS MONITORING

6.1 CEA vide letter dated 16.10.2017 (Annexure-XVIII) had informed that in view of

increasing incidents of Cyber attacks and threat to integrated grid operation, all utilities

need to monitor action being taken with regard to following points and report the status to

respective Computer Emergency Response Teams (CERTs):

a) Appointment of organization-wise Chief Information Security Officers and its status

b) Identification of organization-wise Critical Infrastructure and its status

c) Preparation of organization-wise Crisis Management Plan and its status

d) Status of Cyber Security Mock Drill activity in coordination with CERT-In by power

sector entities.

e) Status of action taken for CERT-In / NCIIPC advisories.

Quarterly action taken report were to be submitted by each utility to Chief Information

Security Officer (CISO) of MoP ie. Chief Engineer (IT) with a copy to RPC Secretariat.

Subsequently CEA had informed that IT Division, CEA and Sectoral CERTs proposed to

make a presentation on "Cyber Security in Power Sector" during the next TCC Meeting.


Chief Engineer (IT), CEA had made a detailed presentation (Annexure-XIX) on cyber

security issues.

Cyber Security Preparedness - since last two years, through CERT (Thermal, Hydro,

Transmission and Distributions) efforts were made to sensitize and prepare all utilities

for cyber security in power system. Not much progress was visible and a lot needs to be

done.

Appointment of organization & plant level Chief Information Security Officers (CISO),

identify organization-wise Critical Infrastructure, formulate Crisis Management Plan

(CMP), Security Mock Drills, Information Sharing & Analysis Centre (ISAC) – Power

& Trainings / workshops on Cyber Security was to be undertaken.

CISO nominations not received : Hydro - private utilities; Thermal - TSGENCO,

KSEBL, APGENCO, IPPs & Nuclear; Transmission - private transmission licensees;

Discoms - Andhra Pradesh (Eastern), Telangana (Central), Kerala (KINESCO,

Infopark), Tamil Nadu (Technopark), Lakshadweep and A & N Islands.

CISO nominations are to be communicated and the Quarterly Preparedness Monitoring

Report to be furnished, as per the enclosed format, in a timely manner.

CE (IT), CEA had informed that National Power Portal (NPP) a Dashboard and Data


analytic for Power Sector at one place had been launched by Hon'ble Power Minister on

14th

November 2017. Data entry for all six applications is being done and report is being

generated in testing phase out of which five to be made operational in next two months.

In case there is any requirement of training, CEA could arrange regional level

workshops. Further, a Geo Spatial Energy Map project under NITI Aayog had been

initiated. ISRO and CEA are preparing Geo spatial map of all generation, transmission

and distribution assets. Any state which wants GIS mapping of its assets above 33 kV

(initially), can get it done free of cost. This Map would be useful for operation and asset

management purposes. Format of the data had been shared by concerned Divisions of

CEA with all state utilities. Data from Transmission and Distribution utilities was

however awaited. Cooperation had been sought from the constituents in both these

initiatives.

TSTRANSCO had pointed out that while audit was being carried out in their system,

there was no approved procedure or clarity on whether the same was adequate. CEA

was kindly requested to come out with some specific guidelines and training on the

subject.

It was agreed that CEA would kindly share the tender document on IT System Audit (of

Himachal Pradesh). States could also approach CEA for any support in this regard.

Third party audit was also to be carried out by empanelled auditors.


7. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER

ENVIRONMENT (PROTECTION) AMENDMENT RULES, 2015

7.1 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 had been 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, 1

st 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 as well as Subcommittee Meetings. Meetings were conducted on 12th

January 2017 and on 25th

March 2017 at SRPC, Bengaluru to deliberate on status and

also to firm up Phasing Plan.

7.2 The following had been noted in earlier Meetings:

SRPC had noted the requirements for necessary compliance.

Chairperson, SRPC vide letter dated 24th

May 2017 addressed to Secretary-Power, MoP

had brought to kind attention of MoP, the issue regarding funding either from PSDF or

any other fund to meet stipulated revised environmental norms.

APGENCO had informed that a Committee has been formed on FGD assessment etc

and the Report would be submitted to the Board shortly. About Rs.1 Crore/MW was

estimated expense for FGD and the issue would be reviewed/decided in the next Board


Meeting. AP was in discussions with M/s BHEL and its team had also visited the power

stations.

NLC had informed that they had appointed M/s Mecon as Consultant and

measurements had been taken at site. The report was expected in about 1-1½ month

and the status would thereafter be communicated to CEA.

Generators had expressed concern on addition expense of about Rs 1-1.5 crore/MW,

space constraints, burden on the utility, economic viability, passing the burden on

consumers/tariff etc

Generators had been suggested to keep CEA kindly apprised of developments in this

matter. Action was to be initiated to adhere to the FGD Plan and also Phasing Out Plan

finalized by CEA/SRPC.

It had been agreed that Chairperson, SRPC be kindly requested to once again take up

the issue regarding funding (PSDF/any other fund) with Ministry of Power, for meeting

the environment norms.

7.3 As agreed in the 32nd

Meeting of SRPC, Chairperson, SRPC vide letter dated 28th

August

2017 (Annexure-XX) had taken up the matter with MoP.

7.4 A Special Meeting to finalize phasing plan of Thermal Units for implementation of new

environmental norms was conducted in SRPC on 18th

September 2017 with participation

of CEA and various stake holders. Draft Plan for FGD implementation and Phasing Out of

units had been frozen. Some of the generators had expressed concern/difficulty in

obtaining approvals and arranging funds etc. In view of the time bound nature and its

criticality Chairperson, SRPC vide letter dated 04.10.2017 (Annexure-XXI) had requested

Chairperson, CERC that the concerns expressed by the generators may kindly be arranged

to be examined.

7.5 NTPC had filed a Petition No.98/MP/2017 in matter of „Petition under Section 79 of the

Electricity Act, 2003 read with Regulation 14(3) (ii) and Regulation 8(3) (ii) of the CERC

(Terms and Condition of Tariff) Regulations,2014 for approval of expenditure on

installation of various Emission control systems as detailed in this Petition for compliance

of MoEF & CC , GoI notification dated 7.12.2015 mandating compliance with revised

environmental norms for thermal power stations‟ In the ROP for date of hearing

27.07.2017, Hon‟ble Commission had admitted the Petition and directed to issue notice to

the Respondents. In the petition NTPC had stated although, the said Notification would

cover all projects of NTPC, present Petition covers indicative expenditure to be incurred

by two generating stations namely, Singrauli STPS and Sipat STPS Stage-I.

7.6 A Meeting had been convened by CEA on 23rd

January 2018 to discuss scheduling priority

to TPPs / Tax exemption to TPPs which had installed Pollution Control Equipment and

generating clean power vis-à-vis TPPs which had not installed Pollution Control

Equipment (CEA letter dated 10.01.2018 is given at Annexure-XXII).


7.7 The following had been noted in the TCC:

TSGENCO vide letter dated 18.02.2018 had informed that Kothagudem Unit 9 & 10 are

now identified for FGD installation with time schedule of 30.06.2022 & 31.12.2022.

Unit 3 had been recommended for retirement while unit 1, 2, 4, 5, 6, 7 & 8 would be

retired by December 2019.

NTPL had informed that LOI had been issued to M/s Development Consultant Pvt Ltd,

Kolkata for Consultancy Service for study and engineering for adhering to

environmental norms.

TCC had recommended that Chairperson SRPC may be kindly requested to again take

up the matter regarding funding of FGD/ other equipment to meet the norms.

NPC had informed that FGD funding could have been considered under NCEF fund

(since fund has dried up in PSDF) but reportedly the NCEF fund has been taken into the

GST regime and may not be available now.

FGD installation plan / phasing out plan as received from CEA was presented. Utilities

were requested to kindly adhere to the action plan finalized. Reportedly, individual

generators had been communicated in this regard by CPCB. In the PSDF Review

Meeting held at Kochi on 05.01.2018, Chairperson, CEA had advised that the FGD

installation plan could also be monitored in the OCC forum.

All stake holders were requested to attend the Meeting scheduled on 23rd

February 2018

(follow up meeting consequent to meeting in CEA on 23.01.2018) on scheduling

priority for environmental norms compliant TPPs. Three options on scheduling priority

and also few other measures to facilitate FGD installation had been suggested for

deliberations.

7.8 SRPC noted the above. SRPC also requested Chairperson, SRPC to kindly take up the

issue again regarding funding of FGD/ other equipment to meet the norms.

8. MOP COMMITTEE ON “NHPC TO BECOME GRID STABILISER USING

HYDRO POWER”

8.1 A Committee had been formed on “NHPC to become Grid Stabilizer using Hydro Power”

vide MoP Office Order dated 10.08.2017. In a large grid like India‟s, the flexibility of

hydro generators viz. overload capability, fast ramping & peaking support etc has immense

value for reliable, secure and economic grid operation. MoP felt that an aggregator may be

needed for balancing of power requirement during peak and off-peak hours, and this role

may be assumed by NHPC Ltd. The Committee had been mandated to examine the issue

on how NHPC can aggregate and use hydro power for peak supply. Further, the

Committee may explore the possibility of the non-peak supply using coal based power.

8.2 Chairperson, SRPC vide letter dated 31.10.2017 (Annexure-XXIII) had brought the

following issues to kind attention of POSOCO for deliberations in the final Meeting of this

Committee:

It was strongly felt that a clear market mechanism was required to be introduced which

could incentivize hydro support for peaking support, ancillary services etc. Resources

belonged to the states and were to be utilized by them in tune with the federal structure.


Focus may need to be on NHPC as an Aggregator and not on performance of intra-state

generators during peak hours.

In the current scenario, Hydel Generation is being optimally utilized keeping in view

the Control area requirements duly, considering normal and contingency situations

based on the releases advised.

It was thus for kind consideration whether scope of NHPC as aggregator could

commence with ISGS Hydro stations initially. This would help in gaining valuable

operating insights into this new concept of Aggregation. The same could be extended to

intra-state generators in the next stage, through introduction of suitable commercial

mechanism.

8.3 Subsequently, it was noted that POSOCO had furnished the final report to MoP.


NLDC had informed that NLDC (as Member Secretary of the Committee) had

submitted the final version of the report to MoP. There were reportedly certain

observations from MoP on this report.

It was noted that views of SR constituents in this regard had already been

communicated by Chairperson, SRPC vide letter dated 31st October 2017.

SR states reiterated that hydro reserves are for meeting control area LGB, RE

Variations, irrigation requirement etc.


9. OPTIMUM HARNESSING OF RE IN SOUTHERN REGION

9.1 Follow up of MoP/SRZC meeting

9.1.1 For actionable items under Southern Regional Zonal Council, a Meeting had been held

on 10th

February 2017 in MoP on matters relating to optimum harnessing of Renewable

Energy Integration in SR without endangering Grid Security. It was to be kindly noted

that the Overarching Agreement in SR is yet to be signed by TANGEDCO. This was

noted as a pending actionable point in the 10th

Meeting of the Standing Committee of the

Southern Zonal Council held on 28.11.2017 at Bengaluru. Utilizing the Overarching

Agreement needed to be kindly contemplated.

SRPC vide letter dated 24.01.2018 (Annexure-XXIV) had requested Chairperson,

TNEB that necessary directions may kindly be arranged be given to TANGEDCO for

signing the Overarching Agreement.

9.1.2 The following was noted in the earlier Meetings with regard to SAMAST:

APTRANSCO had informed that they had prepared a Report and submitted it to

CERC and to NLDC for funding. It was of concern that the amount approved was

only about 1/5th

of the estimate.

TSTRANSCO which had submitted estimate of Rs 85 crores had also endorsed the

views of APTRANSCO. They had emphasized that in case much lower funds are

approved, it may not encourage entities to take up the project in a time bound

manner.


KPTCL had informed that they were preparing the DPR and had also deputed a

Committee to Gujarat and MP to study their proposals. DPR would be finalized by

end of the August 2017.

NLDC was requested to kindly look into the possibility of higher fund approval for

proposals under SAMAST. NLDC had assured that the DPRs under SAMAST

would be possibly relooked. For reliable communication, the grant has been raised to

50 % which was earlier 30 %.

9.1.3 The following was noted in the TCC meeting:

TANGEDCO was again requested to kindly sign the Overarching Agreement. TN had

informed that they had entered into a swap arrangement. The signing of the

Overarching Agreement was under consideration of the Management.

The following had been noted in respect of SAMAST:

TANTRANSCO had informed that PO had been placed on 13.12.2017; and the

project was likely to be completed by 25.05.2018.

APTRANSCO and TSTRANSCO had requested for clarity on 5-Minute scheduling

vs 15-Minute scheduling to place Orders. It was also pointed out that CEA may

need to appropriately incorporate 5-Minute scheduling in its Metering Regulations.

TSTRANSCO had informed that DPR for Rs. 87 Crores had been submitted.

KPTCL had informed that they had placed the Order for meters which is adjustable

to 0-60 minutes. DPR for Rs. 43.3 Crores had been submitted on 08.12.2017.

NLDC had stated that with 5-Minute specifications, the 15-Minute values, if

required, could be computed. 5-Minute scheduling was the recommendation of the

Technical Committee of FOR. The draft report had now been circulated for

comments.

NPC had stated that as per ToR, the need for 5 minute scheduling was to be

examined. The same was needed to be simulated and validated w.r.t. 15-Minute

scheduling before recommending the same to FOR. It needs to be ascertained

whether there would be huge variation between 3 blocks of 5 minutes wrt 15

minute block, for the new scheme to be in place with operational / economic

justification, without AGC in place. Pros and cons of the two options are not

highlighted in the draft report. NPC also informed that the SAMAST schemes are

being considered favorably for enhanced approvals, (50 % for communication and

>50 % for other project aspects).

SRPC deliberations

9.1.4 SRPC noted the above.

9.1.5 Director (Opn), TANTRANSCO stated that before the next SRPC Meeting, the

Overarching Agreement was likely to be signed for Banking/Swap option. They have

entered into Swap arrangement with state(s) in other region.

9.1.6 It was noted that TANGEDCO could sign the Overarching Agreement and only utilize

option of Banking/Swap, as and when, deemed fit. The Overarching Agreement could be

utilized in intraday contingencies for mutual benefit of the states.


9.2 Measures for RE Balancing/Reserve assessment and management

9.2.1 Following issues are being discussed in respect of RE variability in earlier

SRPC/TCC/Subcommittee Meetings :

Lift irrigation/pumping loads optimization

Solar morning and evening ramps

RE and demand variability

Demand response

9.3 Pump mode operation of Nagarjunasagar

9.3.1 The following had been noted in earlier Meetings:

TSGENCO had informed that lift irrigation scheme between N‟ Sagar and Tail Pond

were getting submerged and needed to be elevated. Shifting of the lift irrigation

scheme (under private sector) is under progress. Once lift irrigation scheme gets

elevated and with sufficient available water, units can be operated in pump mode.

CMD, TSTRANSCO & TSGENCO had informed that the Tail Pond reservoir is

ready and was to be handed over to TS. Recently OEM, M/s Hitachi had inspected

all the units and they had approved the commissioning. Tail Pond was for pump

mode and due to some administrative reasons there had been some delay.

MD, APGENCO had informed that the proposal for handing over of the dam has

been submitted to Government and was under consideration. The views expressed in

SRPC Meeting would be communicated to Government to take the decision at the

earliest. Being an interlinked issue with Puluchintala, the handing over was awaiting

formalization. Tail Pond dam was constructed with the intention of utilizing the

N‟Sagar units in pump mode and in addition Tail Pond units were constructed to

utilize 50 MW power.

TCC deliberations

It was noted that on 4th

Feb 2018, 2 units of Nagarjunsagar, TSGENCO had run in

pump mode for more than 6 hours on trial basis. Between 09.01.2018 to 01.02.2018,

units 2 to 8 were tested successfully in pump mode operation. During this season, 3

units only can be operated simultaneously on account of certain constraints in

suction side of the water conducting system.

SRPC deliberations

SRPC placed on record its appreciation of TSGENCO for operationalization of

N‟Sagar units in pump mode.

9.4 Pump Storage Plants

9.4.1 A Meeting had been convened by CEA on 28th

June 2017 (MoM issued on 17.07.2017)

regarding utilization of existing pumps in the country. CEA had informed the following

about upcoming Pump Storage Plants in SR:

State PSP Scheme Status

Andhra Pradesh Upper Sileru (1000 MW) DPR being prepared

Tamil Nadu Kundah (4x125 = 500 MW) DPR prepared.


41st SCPSPSR : 2020-21

Sillahalla-I (4x250 = 1000

MW)

41st SCPSPSR : Execution in

preliminary stage

Sillahalla-II (4x250 = 1000

MW)

4 projects on existing sites

Karnataka Sharavathy (2000 MW) PFR submitted to MoEF

Varahi

Kerala Sholayar-I (810 MW) Survey and investigation

(S&I)/implementation could not

be taken up for want of forest

clearance

Sholayar-II (390 MW)

Poringalkuthu(80 MW)

9.4.2 In its 32nd

Meeting of SRPC, it had been suggested that constituents may kindly pursue the

pumping proposals with concerted efforts.

10. COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF

RENEWABLE ENERGY SOURCES

10.1 CEA vide letter dated 12.04.2017 and 08.05.2017 (enclosing MoP letter dated 06.04.2017)

and in Special Meetings held on 28.06.2017 and 11.09.2017 had observed that it was

obligatory for all grid connected renewable generators to provide necessary facilities for

data communication and data storage and other parameters as may be stipulated. It had

been decided by CEA that respective states would submit weekly reports of data

communication status to CEA as well as to respective RPC / RLDC and NLDC. The issue

had been further discussed in the 4th

Meeting of LVRT / RE issues held on 25th

October

2017 at SRPC, Bengaluru. (Minutes available on SRPC website). The following is updated

status with regard to availability of RE SCADA:

State SCADA availability as on

31.01.2018 Mapped I/C

Remarks

AP Wind: 3700/3820 MW (96.86%)

Solar: 1901/2145 MW (88.62%)

Total: 5601/5965 MW (93.90%)

Pending SCADA availability was for RE

connected distribution level and for which

action had been taken for compliance.

TS Wind: 101/101 MW (100%)

Solar: 2960/3198 MW (92.56%)

Total: 3061/3299 MW (92.79%)

Action for balance SCADA availability at

33 kV and below was being followed up

and notices had been issued.

KA Wind: 3504/3504 MW (100%)

Solar: 3079/3244 MW (94.91%)

Total: 6583/6748 MW (97.55%)

KE Wind: 16/59 MW (27.11%)

Solar: 71/91 MW (78.02%)

Total: 87/150 MW (58%)

TN Wind: 6342/7910 MW (80.18%)

Solar: 648/1950 MW (33.23%)

Total: 6990/9860 MW (70.89%)

Notices had been issued for SS under

10(1) for SCADA availability. 100%

SCADA availability of wind was likely to

be ensured by December 2017.

TANTRANSCO (Communication) and

TANGEDCO (Metering) had jointly

initiated action for Solar SCADA

availability and was targeted to be

completed by March 2018.


10.2 In respect of REMC project, it had been noted that sanction of GoI had been received

during September 2017 and implementation schedule was of 14 months. First kick off

Meeting was conducted on 01st November 2017 at PGCIL office. Site survey at SRLDC

had also been concluded.


11. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE

11.1 In line with the decision taken in the 30th

Meeting of SRPC, Terms of Reference (TOR)

were finalized after consultation with stakeholders in the Subcommittee/Special Meetings.

The objective was to have a Study/Report on the TOR, by means of engaging a

Consultant. Constituent states of SRPC had agreed to share the financial commitment

equally.

11.2 The following had been noted in 32nd

Meeting of SRPC:

States may need to fund this study or else the study could be dropped.

Separate Meeting would be conducted with participation from Constituents‟ / RE

Developers. TANTRANSCO consented to coordinate participation of RE Developers.

11.3 Subsequently, Chairperson, SRPC vide letter dated 12.12.2017 (Annexure-XXV)

addressed to MNRE had proposed that certain specific studies could get initiated under

IGEN – GEC Project being implemented by GIZ in India on behalf of the German

Federal Ministry of Economic Cooperation and Development (BMZ). The following

studies were proposed to be taken up:

Ancillary Services from RE and controlling RE generation from REMC / SCADA

during contingency.

Assessment of balancing requirement, type requirement by each state for meeting RE

target by 2022. Suggesting suitable modality of AGC at the state level.

SRPC deliberations

11.4 SRPC noted that the proposal under Indo German Energy Programme (Green Energy

Corridor) being implemented by GIZ was under consideration of MNRE. Ancillary

Services and Assessment of balancing requirement were sought to be covered under this

proposal.

12. MONITORING OF SCHEMES FUNDED FROM PSDF

12.1 In the 7th

Meeting of NPC held on 08.09.2017 (MOM at Annexure-XXVI) RPCs had

been further requested to examine the implementation of PSDF funded schemes in OCC

& TCC meetings and intimate NPC about any bottlenecks.

12.2 The 6th

Meeting of the Monitoring Group of PSDF was held on 05th

January 2018 at

Kochi. It was observed in the Monitoring Group that the overall progress was not very

satisfactory. There had been delays in signing of the Agreement, seeking release of the


first installment etc. Overall, physical progress actually achieved in respect of schemes

was also not very satisfactory. It had been emphasized in that Meeting that better

utilization was highly essential, especially since progress was also being monitored by

MoP. Out of total grant of Rs. 2080.52 Cr for SR, the disbursed amount was Rs. 161.83 Cr

only (around 8 %) as on 22.12.2017. Letter dated 11th

January 2018 in this regard to SRPC

constituent states is given at Annexure-XXVII. The detailed status is given in Annexure-

XXVIII. Overall status of schemes in SR as on 22.12.2017 is given below:

Sl.

No

.

Region/

entity

Schemes Amount (in Rs. Crore)

Received Sanctioned Under

approval

Input

sought

Recently

received

Not

eligible

Grant

sanctioned

Disbursed

1 AP 5 3 0 1 0 1 295.2 31.52

2 KAR 5 2 0 1 2 0 78.27 26.85

3 KER 7 6 0 0 0 1 581.8 23.30

4 TN 11 4 0 2 5 0 459.39 13.10

5 TS 12 5 0 3 4 0 247.72 24.96

6 PUDU 2 1 0 1 0 0 9.5 0.95

7 PG-SR 1 1 0 0 0 0 378.04 37.80

8 SRPC 2 2 0 0 0 0 30.59 19.01

Total 45 24 0 8 11 2 2080.52 161.83


Chief Engineer (NPC), CEA had informed that about Rs 10,000 Cr (101 proposals) had

been earmarked for various DPRs sanctioned, leaving an amount of Rs 3,360. More than

70 DPRs were also under consideration which could require around Rs 8,000 Cr.

Further, the inflows to the fund during 2017 -18 had considerably reduced (less than Rs

350 Cr till now) and only around Rs 400 Cr was anticipated. This was due to better

discipline by the constituents and also due to the fact that majority of funds was getting

depleted due to RRAS.

APGENCO had expressed concern over the curtailments on the already submitted DPRs

and on the fund release difficulties at NLDC.

Chief Engineer (NPC), CEA had stated that there was clarity on the sanctioned schemes /

amount. There were 24 schemes of SR for which around Rs 2,000 Cr was sanctioned,

while issue was with regard to meager disbursement of around Rs 160 Cr. Higher bodies

were even considering de-sanctioning of those projects in case of inadequate utilization

of fund. All entities were requested to avail the PSDF grant and complete the projects as

per identified timelines. There had some improvement after the Kochi Meeting since new

request for disbursement of Rs 100 crores had been received.

SRPC deliberations

12.4 SRPC requested the constituents to expedite the projects and also availing of the funds in a

time bound manner.

13. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY

13.1 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 operationalize AGC

along with reliable telemetry and communication by 1st April, 2017.

(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.

13.2 In earlier Meetings the following had been noted:

NLDC had informed that mock drill test for about one hour had been conducted at

Dadri. Unit-5 & 6 had responded well and based on that they had filed the Petition.

NLDC had informed the Team had visited Simhadri and it was possible to extend

AGC signal. The details had been communicated to NTPC HQ and further

discussions were likely to take place shortly. Team from NLDC/SRLDC had also

visited NP Kunta and a meeting of the stakeholders would be called.

13.3 Hon‟ble CERC in Petition No. 79/RC/2017 vide Order dated 6th

December, 2017 in the

matter of „Automatic Generation Control (AGC) pilot project‟ had summed the decisions

as follows:

„80. The Commission feels that the implementation of the AGC pilot project is a way

forward in the direction of having adequate reserves to ensure secure grid

operation as also mandated by the National Electricity Policy. The Commission

acknowledges and appreciates the efforts undertaken by NLDC and NTPC for

implementation of this AGC pilot project. The development of secondary reserves

in the country will lead to grid security and reliability. The Commission is pleased

to approve the Commissioning of the AGC Pilot Project between NLDC and NTPC

Dadri Stage-II.

81. Issue No. 1: The Commission finds that 5-minute accounting is possible for this

project, and directs that the same should be implemented for improved record of

AGC signal and the up/down response of the plant. This data will also be utilized

for payment purposes for the mark-up. Settlement of energy charges and deviation

charges shall continue to be on the basis of 15-minute time block.

82. Issue No. 2:The Commission accepts the Petitioner‟s proposal that 50p/unit shall

be the mark-up for both positive AGC generation and negative AGC reduction.


83. Issue No. 3: Quantum (MWh) provided under AGC shall be deducted to arrive at

the net deviation as follows:

Net MWh deviation = (Actual MWh)-(Scheduled MWh)-(AGC MWh).

The generator shall pay deviation charges as per the DSM Regulations according

to this computation.

84. Issue No. 4:The Commission accepts the proposal of the Petitioner that the fixed

cost shall continue to be paid by the beneficiaries while the generator shall be paid

a mark-up at 50p/unit for both positive AGC MWh generation and negative AGC

MWh reduction. Generator shall be paid variable charges (as submitted under

RRAS) from the DSM Pool for quantum of energy generated (positive AGC) and

the same shall be paid by the generator to the DSM Pool for energy reduced

(negative AGC).

85. Issue No. 5: The Commission is of the view that on days when full capacity is

requisitioned, ear-marking a quantum of reserves might not be feasible at this

juncture and needs to be further deliberated with stakeholders. Similarly, the

proposal of allowing regulation down when the schedule is at technical minimum is

not agreed at this stage as it needs further examination in terms of technical

feasibility and impact of going below technical minimum.

86. The Commission directs that similar pilot projects may be replicated by NLDC, in

at least one other regional grid of the country.

87. The Commission would also advise the stakeholders to endeavour to extend optical

fibre connectivity to maximum number of power plants under the control area

jurisdiction of RLDCs so that technical feasibility for participation of more

generating stations under AGC is created.‟

13.4 In the OCC Meeting, NLDC had informed that the AGC for Dadri Units has been put in

place from 04.01.2018. In the 7th

Meeting of NPC (refer Annexure-XXVI) held on

08.09.2017, two aspects had been deliberated as given below:

AGC is the requirement of system operation where in generators had to participate in

frequency regulation.

Ramification of implementation of AGC on tariff.

It had been felt by NPC forum that since this issue pertains to generators and Discoms, it

could be discussed at RPC level. Discussion could include aspects of implementation of

primary and tertiary control also. For this, agenda would be prepared by POSOCO and

routed through NPC Secretariat so as to have commonality and National perspective.

Chief Engineer, NPC vide letter dated 06.02.2018 (Annexure-XXIX) had forwarded the

agenda on AGC for discussion in the TCC/SRPC Meetings. This Agenda had been

prepared by POSOCO as agreed in the 7th

Meeting of NPC.

13.5 Hon‟ble CERC vide Order dated 27.04.2017 had constituted an Expert Group chaired by

Member, CERC with Representatives from CEA, POSOCO and CTU and others

concerned. The mandate was to suggest further steps required to bring power system

operation closer to the national reference frequency of 50 Hz. The Terms of Reference

(TOR) of the Committee were as under:

Review the experience of grid operation in India


Review international experience and practices on grid operation including

standards/requirement of reference frequency.

Review the existing operational band of frequency with due regard to the need for safe,

secure and reliable operation of the grid.

Review the principles of Deviation Settlement Mechanism (DSM) rates, including their

linkage with frequency in the light of the emerging market realities.

Any other matter related to above.

The Report on first three TORs pertaining to frequency control in India had been uploaded

in the website of CERC.

13.6 The following had been noted in the TCC meeting:

NLDC had made a Presentation on „Introduction of Secondary Frequency Control

in Indian Power System‟ (Annexure-XXX). Frequency Variation Index (FVI) was

0.02 for India (much improved for the country) compared to 0.0036 of Central Europe.

The Frequency Control Continuum in India was explained differentiating inertial,

primary, secondary, fast tertiary, slow tertiary, generation scheduling/market and unit

commitment. The timeline of activities, Area Control Error (ACE), data flow in AGC

project, Architecture of the project and other issues were also presented.

Number of issues had been submitted by NPC / NLDC for discussion in the RPC

Forum. It was decided that AGC issues raised by NLDC/NPC would be discussed in a

Special Meeting. Generators, STU, Discoms & SLDCs were requested to kindly study

and attend the Meeting.

NLDC had informed that in respect of AGC at Simhadri, offer had been received from

M/s Siemens. They would convene a Meeting with NTPC on 20th

February and then

the Order would be placed with implementation schedule of 5 to 6 months. Regarding

AGC at NP Kunta, M/s USAID had agreed to take the AGC implementation under

GTG project. On 10.02.2018, after assessment it had been concluded that AGC

implementation at NP Kunta was feasible. A Meeting was planned in about 2 weeks

time. AP utilities as well as SERC were required to be consulted in this regard.

On a query about approval from CERC for AGC at Simhadri, NLDC had clarified that

in its Order, Hon‟ble Commission had agreed for AGC Pilot Project on similar

framework in other region.


14. TTC/ATC

14.1 In earlier Meetings the following had been noted:

In the 4th

Meeting of NPC held on 10th

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.


APTRANSCO had informed that nominations for Nodal Officer and Study Group

would be communicated within a month (Sep 2017) from the new recruitees likely to

join shortly.

14.2 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 Unconverged No No No Yes

TN Yes Yes Yes No Yes Yes

KER Yes Yes Yes No Yes Yes


APSLDC had assured that the system would be in place before the next SRPC

Meeting.

KAR-SLDC had informed that the converged case was being furnished, while Nodal

Officer details would be furnished within a week.

TSTRANSCO had stated that though details were being worked out, the same was not

being put on the web site.

SRLDC had informed that Special Training also could be arranged on any request of

the state utilities.

SRPC noted the above.

14.4 Enhancement in TTC of Southern Region

14.4.1 Revival of TTC/ATC of 500 MW for 10 hrs on Talcher-Kolar HVDC had been taken

up by Chairperson, SRPC (vide letter dated 18.05.2017). This issue was also

discussed in the Meeting convened by NPC on 23.10.2017 (MOM dated 01.11.2017

enclosed as Annexure-XXXI). In the Meeting, it was noted that, „it was decided that

since this issue had been discussed in SRPC for a long time, hence there is a need for

NLDC to come up with the reasons behind the requirement of keeping this additional

margin. These reasons could then be studied through simulation at SRPC level for

their acceptance. NLDC may submit the reasons of keeping additional margin to

SRPC and NPC Division, CEA within two weeks‟.

14.4.2 NLDC vide letter dated 07.12.2017 (relevant portion at Annexure-XXXII) had

communicated its views on this matter to NPC.

14.5 Harmonization of Philosophy of Computation of Total Transfer Capability (TTC)

by POSOCO and CTU between ER-SR & WR-SR

14.5.1 During the Study Meeting held at SRPC on 01.09.2017, it had been noted that CTU

and POSOCO were using different philosophies to compute TTC. This issue was


discussed in a Special Meeting conveyed by NPC on 23rd

October 2017 (refer

Annexure-XXVI). After deliberations, Members had agreed for the following

approach for preparing base load flow case to compute TTC/ATC for the purpose of

operationalization and grant of MTOA:

I. Demand:

As per CEA‟s LGBR/EPS.

II. Generation dispatch priority for base case for calculation of TTC/ATC:

1. MoP Allocations as accepted (Net of Auxiliary Consumption)

2. LTA granted & operationalized & CoD of generation plant achieved.

3. LTA granted on target region and operationalized on target region.

4. MTOA already granted

5. State Generations/State Controlled IPPs (based on historical dispatches)

6. Inter State Generating Stations (ISGS) (including selling under Short term)

Note:

1. In the base case, if the loads get met on considering dispatches from S1.1 to 5,

then S1.6 may not be considered.

2. Any gap can be met from the Short term capacity based on historical

dispatches.

3. For dispatch of Inter State Generating Stations (ISGS) capacities selling under

short-term, CTU may consider dispatches on proportionate basis.

4. Base case to be prepared on all-India basis.

14.5.2 The following had been noted in the TCC Meeting:

TCC had placed on record appreciation of NPC for having converged regarding base

case preparation for grant of MTOA. NPC was requested to similarly kindly finalize

procedure for base case preparation by POSOCO, in respect of STOA.


14.6 TTC Revision beyond the approved/scheduled time of revival

14.6.1 In the 32nd

Meeting of SRPC, after deliberations, it had been agreed that PGCIL would

communicate the revival status at least 2-3 hours before scheduled revival time.

NLDC was suggested to kindly restore the TTC at scheduled revival time in its

TTC/ATC declaration on website.

14.6.2 SRPC vide letter dated 17.10.2017 (Annexure-XXXIII) had taken up this matter with

NLDC. NLDC vide letter dated 24.10.2017 (Annexure-XXXIV) had stated that as per

CERC Order dated 22.02.2014 in Petition No.167/Suo-moto/2012 (para 61), NLDC

had been advised to take care of protocols while allowing collective transactions for

the next day. The same is reproduced below and is self-explanatory:

„In view of the above discussion, we advice NLDC to care of the protocols given below

while allowing collective transactions for the next day:


I. The lines which are within a region and not part of limiting constraints or

credible contingencies may be considered under service at scheduled revival

time. Prior to scheduled revival time, status shall be reconfirmed and if

necessary, transaction shall be rescheduled in case the line has not been

restored.

II. The transmission lines which are inter-regional or part of limiting constraints

or credible contingencies shall not be considered to be in service till these are

actually brought back into service. After putting revival status on web site of

NLDC, the margin shall be released for contingency market, if required.‟

NLDC had thus been curtailing TTC/ATC till 24.00 hrs and once it was known to

constituents that ATC/TTC is curtailed up to 24.00 hrs; power procurement planning

could be carried out by them in advance.

14.6.3 SRPC noted that this procedure being followed by POSOCO was as per provisions of

CERC Order.

14.7 TTC/ATC enhancement – Operational guidelines issued by NRCE

14.7.1 SRPC vide letters dated 13.11.2017 and 20.11.2017 (Annexure-XXXV) had requested

POSOCO to assess the possibility of TTC/ATC enhancement as per operational

guideline for determination of TTC, ATC and TRM for short term horizon (0-3

months) issued by NRCE, keeping in view high demand (Jan-Apr), coal shortage

conditions etc.


MS, SRPC had stated that despite follow up there appeared to be no tangible

progress in this regard. SRPC Secretariat was willing to render assistance in

obtaining the required information but the objective should be to implement the

guideline. Any additional TTC/ATC would be quite helpful in time of contingency

and in availing cheaper power.

NLDC had stated that all required information of SR had been received and

temperature dependent ratings were being considered for SR.

NPC had informed that NRCE had requested transmission licensees to furnish the

details of temperature dependent thermal ratings of terminal equipment and lines.

Most of the information was to be furnished by PGCIL. A follow up letter had also

been issued by NPC.

TCC had requested PGCIL and the concerned entities to kindly furnish the

requisite information at the earliest.


14.8 Talcher-Kolar HVDC S/D

14.8.1 In the OCCM, OCC had recommended that outage of Talcher-Kolar be planned before

December every year (to be followed from 2018-19 onwards). SRTS II may please


kindly appraise their Management in this regard. OCC also suggested that the matter

be further discussed in the ensuing Meetings of TCC/SRPC.

14.8.2 KSEBL vide letter dated 12.02.2018 (Annexure-XXXVI) had stated that annual

shutdown of Talcher-Kolar HVDC link had earlier been availed during March 2017.

This shutdown during high demand period was objected by all constituents. This year,

shutdown had been availed during January 2018. The work was scheduled and again

rescheduled in January 2018 on account of difficulty in getting man power during

Pongal/Sankranthi. The HVDC link is highly critical in importing power to SR. In

view of load generation balance issues, it was suggested that next maintenance may be

availed before Christmas for the 2018-19 block. It was also requested that annual

overhauling of any of the Talcher units may also be planned concurrently so as to

avoid bottling up of generation.


PGCIL had stated that this major activity was to be planned and coordinated with

three regions along-with foreign experts also. There were some issues with regard to

standing crop during Nov/Dec, on account of which this period was to be avoided.

TCC had recommended that shutdown of Talcher-Kolar needs to be availed before

Christmas holidays every year and possibly link it with shutdown of Talcher Stage

II Unit.

PGCIL had assured they would plan the shutdown accordingly, in future.


15 STATUS OF DC IN ISGS

15.1 Issue regarding low DC at NLC TS-II Expansion, NTECL and NTPL had been

deliberated in earlier Meetings of SRPC. Level of generation of some ISG stations is

given below:


NLC had informed that while refractory problems had been rectified, some boiler tube

leakages were surfacing. They had taken up the matter with M/s BHEL and some

modification had been suggested. After material arrival, works would be taken up and

reliability may increase within 3-4 months (by Dec 2017). They had demonstrated

500 MW and were putting all efforts and hopeful of improved performance.

Station Aug-17 Sep-17 Oct-17 Nov-17 Dec-17 Jan-18

NTECL,

Vallur

DC % 60.52 48.59 50.37 68.13 64.36 61.07

PLF (on Actual)

%

49.96 44.25 44.15 51.72 50.97 48.23

NTPL,

Tuticorin

DC % 83.38 28.16 58.10 81.40 99.55 100.15

PLF (on Actual) 76.08 25.40 48.50 64.80 70.83 70.89

NLC TS

II Exp

DC % 22.02 48.82 40.34 61.91 25.62 69.23

PLF (on Actual) 21.18 48.44 40.98 61.46 26.66 67.92


NTPL had informed that they had availed two overhauls and performance would

increase. Presently, the availability was 100 %.

NTECL had informed that Unit-3 was expected back by first week of Jan 2018.


MS, SRPC had informed that the loss in DC wrt normative was 956/272/356 MW

during Nov 2017/Dec 2017/Jan 2018 respectively. Some ISGS (Simhadri-II: 84.80%,

Simhadri-I: 78.32%; Kudgi: 81.24%, NLC II- Stage I: 81.07% NTECL: 67.04%,

NLC II Exp: 50.27% & NTPL: 76.71%) were below the target availability also on a

cumulative basis. While scheduling right is with beneficiary, DC being the sole

prerogative of generator, not being able to meet target availability was a matter of

concern.

NTECL had informed that complete replacement of lube oil lines had been taken for

restoration of the unit after the fire incident. On 6th

January 2018, machine had been

rolled up to 3,000 rpm and vibration was within limit, but then two bearing had failed

(due to entry of foreign material). Therefore, complete filtration had been taken up

(generally done for new machines). The third Unit was now planned to be back on

bars on 21st February 2018. Coal stock was available for 17 days and by the year end,

about 70 % PAF could be achieved (presently 67.04%).

NTPL had informed that 726 MU of energy was lost during the months of September

to November 2017 on account of coal shortage. Till July 2017, PAF had been 95 %.

For the months of December to February (till date) the availability was around 100

%. They were likely to achieve about 80 % PAF by the year end (presently 77 %)

NLC had informed that the TS II Expansion station was now having availability of

75-80 %. Some modification works through OEM had been planned and full

availability was expected during the first quarter of 2018-19.

SRPC deliberations

15.4 Director (P), NLC stated that in respect of TS-II Exp station, all issues had been identified,

and after modification works planned during April 2018, the DC would be maximized. He

stated that NLCIL being a miner & generator, 55 % Technical Minimum during wind

season was affecting its mining operations also. Only about 50 % of surrender was being

offered for trading. AP, Karnataka, Kerala, TN, Telangana and Puducherry had given

(consent MU) / (total surrender MU) of 0/273, 0/41, 4/39, 1048/1699, 263/567 and 61/185

for the period April 2017 to January 2018. Around 8-10 MUs/day of trading option was

being lost. He emphasized that the profit is also being shared with beneficiaries. He

therefore requested the states to maximize the concurrence for trading. Traded quantum of

energy should not be considered for ensuring station schedule above or equal to technical

minimum.

15.5 NTPC also requested for maximization of consent for trading.

15.6 It was noted that some of the URS quantum is being maintained by states as spinning

reserve. It was also informed that sum of schedule of beneficiaries plus traded quantum is

ensured above or equal to technical minimum. This practice was in line with the prevailing

Regulations and had been informed earlier to NLCIL.


15.7 Chairperson, SRPC suggested optimization with regard to communication of consent to

ISGS for trading.

16 FREQUENT TRIPPING OF 765 KV AND 400 KV LINES AND SUSTAINED

OPERATION OF ELEMENTS UNDER HIGH VOLTAGE

16.1 Frequent tripping of 765kV Lines on Over Voltage and Daily Hand Tripping of

765kV Raichur – Kurnool & Nizamabad – Maheshwaram Lines – Stress on EHV

equipment

16.1.1 PGCIL vide letter dated 09.01.2018 (Annexure-XXXVII) had referred to frequent

tripping and switching of 765 kV and 400 kV elements on account of over voltage in

the system. During the past 6 months there had been 120 Nos. of 765 kV Line trippings

on account of operation of Over Voltage Protection and 188 Nos. of Hand Tripping of

765 kV & 400 kV Lines for voltage regulation.

16.1.2 On a daily basis, SRLDC was issuing codes for taking 765 kV Raichur – Kurnool ckt 2

(without LR) and 765 kV Nizamabad – Maheshwaram Line 1 or 2 out of service,

(during night) and taking back into service early morning. Average power flow on

above 765 kV lines was only about 250 MW to 500 MW each during off peak and peak

hours.

16.1.3 On account of high voltage in the system and also due to frequent tripping/switching of

765 kV and 400 kV Lines, the EHV & GIS equipment are getting over stressed and

prone to early failure.

16.1.4 Instead of operating the lines in and out on daily basis, alternate methods of operation

could be explored.


PGCIL had expressed concern over frequent operation of breakers and sustained

operation of elements on high voltage. This was stressing the equipment and

making them prone to failure. In case of double circuit lines, one of the lines was

being opened on rotation basis. It would be better in case, a line is allowed to be

kept open for say 15 days continuously so as to minimize number of breaker

operations.

SR-II had stated that in some cases it is well known that line would be taken out

due to overvoltage (as night progresses). Then SRLDC need not wait till voltage

reach > 430 kV (sometimes line are tripping on overvoltage). A preemptive

decision could be taken to take out the line in such circumstances so as to avoid

unnecessary stress on equipment.

POSOCO had stated that opening of lines was being undertaken as a last resort.

Sometimes a line was to be taken in/out on daily basis since intra-day variations

were quite significant. There were associated reliability issues also. However, they

would examine this matter and consider minimizing number of breaker operations

and preemptive taking out of lines.



16.2 Issue of prevailing over voltages in SR Grid

16.2.1 PGCIL vide letter dated 09.01.2018 (refer Annexure-XXXVII) had stated that over

voltages are prevailing in SR Grid despite utilization of services of Reactors and

tripping of lightly loaded transmission lines especially during night hours during last 6

months. These over voltages lead to over stress to substation equipment including

ICTs, Reactors, CVTs, CTs etc. Life span of equipment was also affected adversely

leading to early failures. The following substations were mostly experiencing over

voltages in SRTS-2.

I. (i) Karaikudi, (ii) Karur (iii) Sriperumbudur.

II. (ii) Tumkur, (ii) Bidadi, (iii) Mysore, (iv) Narendra (v) Hassan

16.2.2 In the operational feedback, POSOCO for the quarter (July-September 2017) had

highlighted high voltage nodes (25 nodes at 400 kV & 765 kV). List of lines which

were opened by real time operators to control over voltage in the grid were also

displayed.

16.2.3 In the 136th

Meeting of OCC, SRLDC had observed that 400 kV voltages at NP Kunta

substation were above 410 kV for considerable time (more than 50 %) and some of the

days though out the day. At present settings at STATCOM are at 420 kV & 380 kV, and

it was noted that available STATCOM could not be effectively utilized for mitigating

high voltage. Powergrid had been requested to revise voltage settings to 410 kV.

Subsequently, vide letter dated 20.10.2017 SRLDC had requested Powergrid to revise

the present voltage settings to 390 kV and 410 kV at the earliest. The confirmation from

PGCIL in this regard was awaited.


Details of nodes of high voltage coupled with MVAR injection during October

2017 to January 2018 are given below:

Nodes with MVAR injection during V > 103%

AP KAR KER TN TS

Cuddapah Bidadi Kochi Alamathy Gajwel

Chittoor Munirabad Trivandrum Kalavinthapattu Hyderabad

Gazuwaka Mysore

Karaikudi Khammam

Kurnool Madhugiri

Pugalur Mehaboobnagar

Nellore PG Nelamangala

S V Chatram Malkaram

NP Kunta Pavagada

Trichy Warangal

Vijayawada Raichur

Dichipally

Maheshwaram


Payments being on net basis in Reactive Energy Account, this operational

requirement is not getting adequately highlighted, since MVAR injection at high

voltage needs to be avoided as per IEGC provisions.

SRLDC had expressed concern over high voltage at number of other 765 kV & 400

kV nodes for considerable duration of time. High voltage was getting severe during

night times when solar generation is not there, loads are minimal, line loadings are

very less etc.

TSTRANSCO had stated that VAR injection of solar generators during night times

needs to be restricted and there should be a Regulatory mechanism with more

clarity on this issue.

CE (NPC) had suggested that during night, solar generators could be considered as

load. Thus, similar provisions as for loads (in the state) could be made applicable to

them.

Concerned TRANSCOs had been requested to kindly take appropriate action in this

regard. Issue of high voltage could be further taken up in the Standing Committee

on Power System Planning to ascertain whether there was any further need for

reactors.

PGCIL had informed that set points of NP Kunta Statcom had been modified to

390 kV and 410 kV. TCC had thanked PGCIL for having implemented the revised

set points in the NP Kunta Statcom.


17 ISSUES IN RESPECT OF NPCIL

SRPC vide letter dated 23.11.2017 (Annexure-XXXVIII) had taken up certain pending

issues with NPCIL. NPCIL vide letter dated 24.11.2017 (Annexure-XXXIX) had replied

to this SRPC letter. A Special Meeting with NPCIL was also conducted on 11th

January

2018 to discuss the pending issues (MOM available on SRPC website).

17.1 Balance dues from Beneficiaries

Issue of outstanding dues to NPCIL of Southern Region beneficiaries had been discussed

in the 32nd

Meeting of SRPC. All beneficiaries had assured affirmative action in this

regard. NPCIL vide letter dated 24.11.2017 had expressed concern and stated that the

situation had worsened. The outstanding dues to NPCIL as on 31.10.2017 are as follows:

Utility Amount

TNEB Rs.1270 Crores

KARNATAKA Rs.436 Crores

APTRANSCO Rs.20 Crores

TELANGANA Rs.115 Crores

SRPC vide letter dated 29.11.2017 (Annexure-XL) had taken up this issue with

beneficiaries for expediting and settling the dues at the earliest.

Subsequently, Director (Finance), NPCIL vide letter dated 01.02.2018 (Annexure-XLI)

had again brought attention the high outstanding dues of NPCIL for more than 60 days. As


per statement enclosed, an amount of Rs. 1,045 Cores was outstanding from various state

utilities to NPCIL. Concerned utilities had been requested to kindly arrange action to clear

outstanding dues to NPCIL.

TCC deliberations

KPTCL informed that PCKL had taken up this matter with all Discoms.

TANGEDCO/TSTRANSCO had assured of early settlement of dues.

NPCIL had expressed grave concern on the non-timely clearance of the dues.

Constituents were again requested to kindly clear the dues at the earliest.

SRPC requested the constituents to kindly clear the dues at an early date.

17.2 Part load operation of KKNPP Unit-II

KKNPP Unit-II had been revived on 20.11.2017 after prolonged outage since

04.08.2017. It was noted in the OCCM that Unit would be taken out for refueling after 3

months of full load of operation. OCC (in 137th

, 138th

& 139th

Meetings) had

recommended that this unit needs to be on bars till end of March 2018 which could be

possible through part load operation of the unit. SRPC vide letter dated 23.11.2017 had

taken up this issue with NPCIL. NPCIL vide letter dated 24.11.2017 had informed that

the request has been duly communicated to Director (Operation), NPCIL for

consideration. In the Meeting held on 11.01.2018, KKNPP/NPCIL citing

technical/economic constraints had stated that the unit would be taken out on

01.03.2018. TANTRANSCO vide letter dated 11.01.2018 (Annexure-XLII) had again

requested NPCIL to operate Unit-II at KKNPP on partial load till end of March 2018 as

done in earlier occasion. Else, the schedule outage may be postponed to June 2018 for

benefit of Southern Region. KKNPP/NPCIL was once again requested to consider this

request of OCC for part load operation upto end of March 2018.

TCC deliberations

TANTRANCO had expressed concern that KKNPP being a large unit ( 1,000 MW),

its frequent forced outage, delay in revival (beyond schedule), taking out of unit

during peak months , not considering part load operation etc was making the task of

system operators further difficult. All NPCIL units should be planned for

maintenance only during June to December each year. With higher RE penetration,

NPCIL units need to offer some flexibility (seasonal, part load etc) which was need

of the hour.

NPCIL had informed that as noted in the 11th

January 2018 Meeting, part load

operation of unit was not possible on account of various technical/commercial

constraints. Performance of nuclear units was very stable and only during forced

outages/equipment problems, there had been some delay. At KKNPP, all the

equipment are imported, which has its inherent delay. Kaiga units had created record

of maximum running days. Forced outages happen despite taking all measures and

these have to be attended. As informed in last SRPC Meeting, maintenance of all

units of NPCIL of SR (except KKNPP) would be planned during June to December.

KKNPP has a 10 month (300 days) cycle and thus maintenance has to be availed as

per that cycle. In future, the cycle could increase to 18 months (after 5-6 cycles of 10

months) and at that time some flexibility could be considered.


It was noted that commercial issues should not be linked with technical issues in

respect of part load operation. NPCIL had stated that technical issues as being

highlighted are the main reason for not agreeing to part load operation. However,

commercial issues of NPCIL (pending payment) should also not get ignored.

17.3 Closing of 2nd

ICT at KKNPP

In the OCC Meetings, it was noted that KKNPP was keeping one ICT permanently out

on 230 kV side (out of two ICTs). SRLDC had suggested closing the ICT which was

not complied by KKNPP. SRPC vide letter dated 20.11.2017 had taken up the issue

with SRLDC for compliance. SRLDC vide letter dated 07.12.2017 had also taken up

this issue with KKNPP. NPCIL vide letter dated 08.12.2017 had expressed their

concern over the issue. In the Meeting held on 11.01.2018, after deliberation, NPCIL

had agreed in principle to close both ICTs keeping in view the enhanced reliability (for

N-2) and reduced losses. Protection settings would be vetted by PRDC, SRLDC and

SRPC in coordination with NPCIL. NPCIL would take the final decision on the

protection settings and the ICTs would be closed. SRLDC assured of all necessary

assistance in case of any sustained overloading of KKNPP – SR Pudur line. Forum had

also requested TANTRANSCO to kindly ensure healthiness of KKNPP – SR Pudur

and KKNPP – Tuticorin lines.

TCC deliberations

NPCIL had informed that they would take 2nd

ICT in service and the vetting of

protection settings would be expedited.

TANTRANSCO had assured of adequate measures to ensure healthiness of 230

KV KKNPP – SR Pudur and KKNPP – Tuticorin lines.

17.4 Wrong operation of opening of Kaiga-Kadra line instead of Kaiga-Kodasalli line on

23.11.2017

In the Meeting held on 11.01.2018, KGS had informed that the issue regarding wrong

operation had been viewed seriously and necessary instructions had been

communicated for strict compliance to avoid recurrence of such incidents in future.

NPCIL also assured of corrective action in this regard.

17.5 Delay in charging 220 kV Kaiga-Kadra line on 23.11.2017 by NPCIL, Kaiga

Opening of Kaiga – Kadra line had resulted in 220 kV bus dead at Kadra and also 220

kV Karwar station (60 MW load) got interrupted. Kaiga was requested to charge 220

kV Kaiga – Kadra line at the earliest. It was noted with concern that despite continuous

efforts of SRLDC & KPTCL SLDC, Kaiga was reluctant to charge the line and for

more than two hours, instructions of SRLDC had not been complied. In the Meeting

held on 11.01.2018, after deliberations, it had been agreed that Kaiga GS, MAPS and

KKNPP would share details of the Control Room in-charge and Operation

Superintendent for single point contact during such emergent conditions. All

instructions of SRLDC would need to be complied say within 10 minutes. NPCIL

would pass necessary instruction in this regard to the stations (copy to be furnished to

SRPC/SRLDC). Necessary power would also be delegated to Control Room to ensure

compliance of SRLDC instructions in a time bound manner.


TCC deliberations

NPCIL had informed that they had formulated a procedure for closing healthy lines

in the event of any inadvertent switching operations.

Details of single point contact would be communicated, wherever pending.

17.6 Black Start Mock Drill at Kaiga GS and MAPS

In the Meeting held on 11.01.2018, KGS had informed that Black Start Mock Drill

would be taken up during BSD of the units on similar lines to KKNPP. Unit-I BSD

was planned during July/August 2018. MAPS had communicated that BSRP for

MAPS had been prepared and communicated to M/s TANTRANSCO, LD Centre,

Chennai for review and approval. MAPS would conduct the mock drill under

intimation to SRLDC/SRPC. It was noted that MAPS unit-II BSD had been planned

during May/June 2018 shutdown.

TCC deliberations

Kaiga Unit –I BSD was planned during July/Aug 2018 and BSRP mock drill for

Stage I would be taken up at that time.

MAPS Unit is out and mock drill can be carried out. Procedure had been

communicated to TNSLDC.

MAPS/TNSLDC/SRLDC agreed to take up the mock drill.

17.7 PSS tuning / SRT

In the Meeting held on 11.01.2018, Kaiga GS had informed that the SRT for Unit-I

would be taken up after BSD (July/August 2018) in which, AVR was being planned to

be replaced with DVR and PSS tuning / SRT would be taken up. SRT of Unit-III

would be taken up after BSD (December 2018/January 2019). MAPS had

communicated that training had been conducted at NPCIL HQ in respect of PSS. It was

understood that NPCIL HQ would prepare a common procedure for sites for

conducting SRT. NPCIL had informed that they would coordinate and the SRT would

be undertaken around BSD for both the units. BSD for Unit-II was planned during

May-June 2018.

TCC deliberations

PSS tuning/SRT of Kaiga Unit –I would be taken up after BSD (July-Aug 2018).

PSS tuning/SRT of Kaiga Unit-III would be taken up during Dec 2018-Jan 2019.

MAPS Unit –II PSS tuning/SRT during May – June 2018.


17.8 MVAR inter-change analysis

In the Meeting held on 11.01.2018, KKNPP had agreed to revert back regarding

MVAR interchange for Unit-II (even for high voltages it was not absorbing). NPCIL

had also agreed to revert back on MVAR interchange for MAPS Unit-I & II which

were injecting even above 230 kV.

TCC deliberations

Regarding units injecting even above 230 KV, MAPS had stated that they would

look into this issue.

KKNPP would revert back regarding Unit-II MVAR interchange.


17.9 MVAR testing for Kaiga GS Unit

In the Meeting held on 11.01.2018, Kaiga GS / NPCIL had agreed in principle for

MVAR testing of Kaiga GS units III/IV. SRLDC had assured that all concerns of

Kaiga GS would be adequately taken care.Testing would be well within the

capability/limiter set points and other temperature / load angle constraints. Dates for

testing would be communicated by Kaiga GS within 10 days.

TCC deliberations

NPCIL had informed that Kaiga Unit –IV MVAR testing could be conducted

(within capability curve and limiter setting).

17.10 2x125 MVAR Reactor commissioning at Kaiga GS

In the Meeting held on 11.01.2018, NPCIL had informed that the tender for one of the

reactor along with bay works was planned to be floated within 20 days. LOA was

likely to be placed within 6 months and they were hopeful to complete the reactor

commissioning by December 2019. For the other reactor, they were planning to

exchange 63 MVAR reactor with 125 MVAR reactor of PGCIL and they would get in

touch with PGCIL in this regard.

TCC deliberations

NPCIL had informed that one reactor would be commissioned by December 2019.

In respect of the 2nd

reactor, they would get in touch with PGCIL shortly.

17.11 Revival of Reactors under forced outage at KKNPP

In the Meeting held on 11.01.2018, KKNPP had informed that the bushing (imported)

for one of the reactor had been received and work order awarded. Works were planned

to be completed by 28th

February 2018.Rectification for the other reactor would be

taken up in April/May 2018 and expected to be completed by December 2018.

TCC deliberations

NPCIL had informed that first reactor had been commissioned on 14th

Feb 2018.

Second reactor would be revived by Dec 2018.

17.12 SCADA issues

In the Meeting held on 11.01.2018, regarding RTU it was concluded that

KKNPP/KGS may need to take up works through alternate vendor (M/s OSI was also

providing RTU services) as a long term solution. In the meantime, KKNPP could

pursue the matter with SR-II / KPTCL for the spare analog data card. NPCIL stations

were requested to attend the data discrepancy and pending field inputs in respect of

Kaiga GS, MAPS and KKNPP.

TCC deliberations

PGCIL has kindly made available the cards to NPCIL.

NPCIL had agreed to address the other issues.

17.13 Protection related issues

With regard to A/R implementation on MAPS lines, NPCIL had informed that

procurement of required line CVTs was under progress. Commissioning of CVTs


and A/R enabling on all the four 220 kV lines was targeted to be completed by

March 2018. MAPS had informed that PO for A/R facility was released for

procurement of the CVTs. A/R for the lines would be implemented after receiving

the CVTs.

With regard to A/R implementation for 220 kV KKNPP – SR Pudur line, NPCIL had

stated that they would revert back with details in the next Meeting of PCSC.

As part of GSC (Task-II), 220 kV Kaiga GS had been audited by M/s Tractebel

Engineering (TE) during 4-6 April 2016, when certain recommendations were given

for compliance. Status of compliance of these recommendations viz., separation /

redundancy wrt Differential and REF protections of ICT 1 & 2, disabling of Over

Current (67) protection on all 220 kV feeders, revising of LBB timing and time

synchronization of Main-I and Main II protections with GPS were discussed. KGS

was asked to kindly take steps to provide the same at the earliest and furnish latest

status in this regard to PCSC forum.

TCC deliberations

NPCIL had informed that Auto reclosure for MAPS line would be commissioned

by Sept 2018.

17.14 Delayed DC revision by Kaiga GS

Kaiga GS had been suggested to have redundant service provider for the internet (M/s

Powertel could be approached as OFC had been reportedly laid). The issue had been

earlier discussed and NPCIL station had assured of corrective action in this regard.

NPCIL had been requested to issue suitable guideline to the stations.

TCC deliberations

NPCIL had assured of reliable redundant internet connectivity. Also that DC

revision would be carried out prudently and in timely manner.

17.15 Testing schedule by KKNPP

SRLDC had informed that KKNPP was not getting testing schedule approved by OCC

and request was coming with 2-3 days of notice only. Testing activity was having

impact on the IR flows also and it would be prudent to inform and get the testing

schedule approved by OCC as was being done by KKNPP earlier. KKNPP/NPCIL had

assured of necessary compliance in this regard.

TCC deliberations

NPCIL had assured of communicating the testing schedule in a timely manner in

future.

17.16 Commercial Issues

SRLDC pointed out that Rs. 1,725 (interest) was due from KKNPP in the DSM

Account during the period of infirm injection when KKNPP was Member of the DSM

pool. KKNPP agreed for clearing the dues at the earliest.

SRLDC pointed out that for MAPS LV side GT, SEM values are not being

communicated (which were earlier being communicated). NPCIL agreed to look into

the matter.


TCC deliberations

NPCIL had assured that balance dues would be cleared. Other issue regarding

communication of SEM values would also be addressed.

17.17 SRPC noted the above in respect of NPCIL issues.

18 UPCOMING TRANSMISSION SYSTEM

18.1 41st Standing Committee on PSPSR

Minutes of Meeting of 41st Meeting of Standing Committee on PSPSR (meeting held on

22.09.2017) had been issued on 06th

December 2017 (available on CEA web site).

SRPC noted the above

18.2 MOP Committee on POC

18.2.1 Ministry of Power vide Order dated 27.10.2017 (Annexure-XLIII) had constituted a

Committee to review transmission tariff including Point of Connection Charges (POC)

charges and suggested simple methodology for calculation of transmission tariff.

Representative from Karnataka was a Member of this Committee. Terms of Reference

(TOR) of the Committee are as follows:

a) Study the present mechanism of POC and recommend simplification of calculation

methodology for calculation of transmission charges.

b) To bring transparency in calculation of transmission charges (existing and at least

for the ensuing year) and the calculation on the public domain.

c) Any other issues relating to transmission tariff to meet stated objective.

On this subject, a Meeting was held at MoP on 24th

November 2017.

18.2.2 In Petition No. 12/SM/2017 along-with I.A. No. 54/2017, Hon‟ble CERC vide ROP for

date of hearing 14.09.2017 had noted, „….4. The Commission directed CTU to submit

on affidavit, on or before 5.10.2017, the details of LTA customers for whom LTAs had

not been operationalized in terms of Regulations 8(5) of the Sharing Regulations w.e.f.

1.5.2015.‟

TCC deliberations

TANGEDCO had stated that they would also like to be a Member of the MoP

Committee since some important issues were needed to be addressed.

It was noted that this Committee was to submit its report by 15th

Feb 2018.

It was also noted that views of TANGEDCO were placed under record by the

Committee under CERC. TANGEDCO had made a presentation to that Committee.

Also on 20th

February 2018, the CERC Committee was again scheduled to meet and

thus TANGEDCO could consider again approaching it appropriately.


18.3 Upcoming inter-regional transmission schemes

18.3.1 Updated status is furnished below please:

S S.No. Transmission Element Remarks

a) WR-SR 6000 MW HVDC Bipole

Link [Raigarh (Chhatisgarh) -

Pugalur-Trichur (TN/KER)]

Apr’ 2020


31st TCC:

PGCIL informed that the works at both the terminals had commenced. The

line works from Raigarh to Pugalur had started in all the regions (WR-I, SR-I

& SR-II). Top management was putting all efforts to complete the works by

December 2019. Efforts are also being made to advance it.

PGCIL (Dec 2017): Efforts being made to complete one pole by Mar

2019. 320 kV Pugalur-Trichur HVDC by Dec 2020.

32nd

TCC: 800 kV December 2018. 320 kV: September 2019.

b) 765 kV Angul - Srikakulam PS D/C

Corridor

Main corridor commissioned.

Other associated elements by July

2018.

31st TCC :

PGCIL informed that Garividi- Srikakulam PS was expected by March 2018.

APTRANSCO informed that the downstream system would also match.

Removal of constraints in Vemagiri area was expected to be completed by

October 2017. APTRANSCO expressed concern over the line loading issues

in Vemagiri area.

41st SCPSPSR:

It was agreed to drop the proposal of CTU for temporary Rearrangement

of 400 kV Vemagiri-I(AP)-Vemagiri-II(PG) D/C transmission line.

32nd

TCC: PGCIL informed that Garividi- Srikakulam PS was expected

by May/ June 2018. AP informed that downstream system is ready.

c) 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 on 06.07.2016

(around Nov 2019).

Discussed in 36th

Meeting of

Empowered Committee held

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).

32nd

SRPC: PGCIL had informed that the line was under TBCB but bay

extension at Warangal, Hyderabad & Kurnool had already been started.

CEA (Nov 2017): Nov 2019.

32nd

TCC: There was a Meeting held to consider proponing of

Hyderabad-Kurnool line. It was concluded that further study may be

required before concurring for this preponement. One more Meeting

was to be held.

d) System strengthening within SR for

transmitting power beyond Vemagiri

TBCB- RECTPCL-BPC–Some

scope of work/ reactive

compensation modified.

Project has been awarded to

PGCIL under TBCB, and was

expected by April 2019.


31st TCC:

PGCIL informed that 765 kV Vemagiri – Chilkaluripeta – Cuddapah D/C and

400 kV Cuddapah – Madhugiri D/C expected by Q1 of 2018-19.

41st SCPSPSR:

It was agreed to drop the proposal of CTU for temporary Rearrangement

of 400 kV Vemagiri-I(AP)-Vemagiri-II(PG) D/C transmission line.

It was agreed to hold a meeting in CEA for Early commissioning of

transmission scheme covered under “Strengthening of Transmission

system beyond Vemagiri” with CTU, LTTCs and the TSP.

32nd

TCC:

Chilkaluripeta – Cuddapah line was stuck up for want of wild life (Tiger

Conservation Reserve) clearance. It requires forest clearance from

AP/TS/Central Govts. They had taken up the issue since Tiger

Conservation Reserve is yet not in public domain, they may not to be

obligated to take this clearance. There were AP lines also stuck up due to

the same issue. The line would come up in Q3 of 2018-19.

Cuddapah – Madhugiri Q2 of 2018 – 19.

18.3.2 Updated detailed status of upcoming inter regional scheme is furnished at Annexure-

XLIV.

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

Raichur- Sholapur line (Out of planned 18 elements)

18.4.1 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

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

Raichur- Sholapur line (Out of planned 18 elements)

1 400 kV Tumkur-

Yelahanka D/C

line

PGCIL

(132

Ckm)

June 2014 31st TCC/

PGCIL

(Dec 2017) :

Sep 2018

Severe RoW

problem. 400 kV

Yelahanka S/S is

ready.

2 400 kV

Nelamangala-

Hoody LILO at

kV Yelahanka

PGCIL

(20

Ckm)

32nd

TCC:

February

2018

PGCIL following up

State Administration

for removal of ROW

issues for LILO

Nelamangala-Hoody

3 220 kV Tumkur –

Antharasana Halli

D/C

KPTCL LOA placed

on 18.03.15

with 18

months

completion

schedule

32nd

TCC:

March

2018

4 220 kV Tumkur

(400 kV) S/S –

220 kV Tumkur

S/S D/C

KPTCL 32nd

TCC:

March

2018

31st TCC :

All towers completed

and stringing of 4

kms to be carried out.


18.5 Status of important Transmission Systems

18.5.1 Updated status of associated links is furnished below please:

Transmission

Elements

Line

Length

(ckm)

Implem

enting

Agency

Sch

COD

Ant

COD/

Act

COD

Constraints/

Remarks

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

Power Ltd, Tuticorin Area

765 kV S/C Salem PS

(Dharmapuri) -

Madhugiri P S line

(initially charged at

400 kV)

243.23 PGCIL Dec'14 32nd

TCC:

March

2018

Severe ROW

problems in

Karnataka. Critical.

Covered under

PRAGATI.

Transmission system associated with IPPs of Nagapattinam/Cuddalore Area–

Package A

Salem New –

Madhugiri 765 kV S/C

line.

219 (PNMT

CL) (A

subsidia

ry of

PGCIL)

Mar‟

15 32

nd

TCC:

June

2018

Severe RoW issues

being faced in

Karnataka.

PGCIL (Dec 2017):

Issue highlighted to

PMO level.

Transmission System Associated with Contingency plan for Evacuation of Power

from IL&FS ( 2 x 600 MW)

Stringing/ upgradation was pending within NLC Complex. PGCIL had planned it during

October 2017.

5 220 kV

Yelahanka

(400/220 kV)

S/S- 220 kV

Yelahanka S/S

D/C Cable

KPTCL (11.75 Ckm) 32nd

TCC:

April 2018

1.5 km/ 5.8

km

completed

31st TCC :

Cable had been

received, ROW issues

being resolved.

139th

OCC

(11.12.17):

Road Cutting

permission issued by

KRDCL vide letter

dated 29.11.2017.

Panchayat

permission yet to be

received. Works were

likely to be

completed by March

2018.

PGCIL letter dated 09.01.2018 (refer Annexure-XXXVII) had stated that for

utilization of 2 x 500 MVA Transformers at Madhugiri Substation, 220 kV

downstream lines i.e. Madhugiri-Anthranasahalli, Madhugiri-Nittur and Madhugiri-

Madhugiri-II needs to be commissioned for utilization of the system.


Transmission evacuation system for HNPCL (1,040 MW) Power Plant

400 kV TM D/C

Kamavarapukota -

Vemagiri

185 APTRA

NSCO

31st TCC:

Alternate options being explored,

would be taken up with the

Standing Committee.

Suryapet Substation 2x315

TSTRA

NSCO

ICT-I

charged

on

31.3.16

ICT-2 charged on

17.03.2017

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

MW in Phase-I) of NTPC Limited

220 kV D/C line to

Vajramatti

KPTCL Feb

2017

Awarde

d – 1

year

June

2018

220 kV D/C line to

Basavana Bagewadi

72.60

KPTCL Dec 2017

30th

TCC :

50% complete

220 kV D/C line to

Bijapur

KPTCL Dec 2017

30th

TCC :

50% complete

Transmission System for evacuation of power from Singareni Collieries

Generating Project (2 x 600 MW)

STPP, Jaipur –

Jagityal

139 TSTRA

NSCO

31st

TCC:

Nov 17

Works Awarded on

Nov‟15.

Jagityal - Nirmal 148 TSTRA

NSCO

Feb 17 Ready 31st TCC : Nirmal

SS by Nov 2017

Transmission system of KPTCL for evacuation of power from Yermarus TPS ( 2 x

800 MW)

Bellary 400 kV PS

near „BTPS‟

Compl

eted

32nd

TCC: March

2018. Land acquired

from KIADB and

some job assurance

issue was being

addressed.

Gulbarga 400/220 kV

substation

2 x 500

Land acquired.

Estimate to be

prepared.

Yermarus TPS -

Gulbarga 400 kV D/C

line (QM)

Detailed survey

completed. Estimate

is being prepared.

400 kV SS at

Chikkanayakanahalli

(C.N Halli) near LILO

point on the

Nelamangala –

Talaguppa 400 kV

lines to Hassan.

2 x 500

MVA

Step-

down SS

agreed in

39th

SCPSPS

30

th TCC:

Land yet to be

identified. Alternate

site at Bindikere is

under consideration.

Land acquisition is

under progress.


R

LILO of Nelamangala

– Talaguppa 400 kV

D/C at CN Halli.

Linked with CN Halli

station

Land acquisition is

under progress

Termination of 400

kV D/C of Hassan

from Nelamangala –

Talaguppa at CN Halli

400

After CN Halli land

identification, survey

would be taken up.

Yermarus TPS -

Bellary PS 400 kV

D/C QM

(400 kV MC (5.138

Kms) and 400 kV D/C

line(137.355 Km) =

142.493 Kms)

285

Sept

2017

Dec

2017

213 ckm out of 285

completed

Bellary PS -

C.N.Hally 400 kV

D/C line QM

360

29

th TCC update:

Part of the work from

Rampura-Jagalur 65

kM had been

awarded.

Bellary PS to

Madhugiri (PGCIL)

a) Madhugiri to

Rampura limits):

400 kV D/C QM

Bellary PS to

Rampura limits

(KelaginaKanavi)

188.74

43.018

364

86

22-12-

16

24-04-

17

Comple

ted

Comple

ted

31st TCC :

Testing under

progress. Would be

commissioned

shortly.

De-link 400 kV S/C

RTPS-BTPS-JSW-

Guttur with JSW Bus

Nov‟16 Agreed in 39

th

SCPSPSR

Once 400 kV M/C

line from JSW to

BPS the link between

JSW & BPS will be

delinked.

JSW TPS – BPS

Station 400 kV D/C

line QM

Comple

ted

Additional JSW TPS –

BPS 400 kV D/C

(QM)

Agreed in 39

th

SCPSPSR

400 kV BTPS-Guttur

D/C (QM)

Agreed in 39th

SCPSPSR

Transmission System for Rayalaseema TPS (600 MW)

RTPP - Pedda

Jamgam Palli -

Chittoor

216+

212

APTRA

NSCO

Test

charge

on


22.05.2

017

400/220 kV, Kalikiri

S/S

2 x 315

MVA

APTRA

NSCO

Sep‟17 30th

TCC:

2018-

19

PO is placed in Nov-

15. Site handed over

on 23.06.2016

LILO of Rayalseema

IV-Chittoor 400 kV

D/C at Kalikiri

81

APTRA

NSCO

Status of upcoming links having impact on S1-S2

400 kV Somanahalli-

Dharmapuri PS

244 PGCIL Jun‟15 32nd

TCC:

June

2018

Severe RoW

problems being faced

in Karnataka.

Compensation issues

under progress.

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. It would take around two months to complete the work once ROW issues are

resolved.

400 kV Mangalore

(UPCL ) -Kasargode-

Kozhikode

TBCB

41st SCPSPSR: A meeting was held in CEA on 28.08.2017. In the joint meeting, system studies were carried out

by considering the KSEB‟s proposal as well as proposal of Udupi Power Corporation Limited (UPCL) for

evacuation of power from their proposed additional generating (2 x 800 MW) units and following was agreed:

(i) There is requirement of additional (i.e. 2nd) double circuit outlets from Udupi switchyard. Replacing existing

conductors of 400kV D/C Udupi-Hassan line by HTLS conductors proposed by KPTCL would not serve the

purpose of evacuation of total power generated at Udupi (2 x 600 MW + 2 x 800 MW) under N-1 Criteria.

(ii) A team comprising of officers from KPTCL, KSEBL and UPCL would visit UPCL generation switchyard to

assess the space availability to accommodate additional bays including Bus Reactor bays to establish 400 kV D/C

Link between Udupi & Kasargode.

29.7 Representative of KSEB stated that team comprising of officers from KPTCL, KSEBL and UPCL had visited

UPCL generation switchyard to explore feasibility of space for proposed extension. The team had observed the

following:

(i) Sufficient space is available for accommodating the two line bays for Udupi - Kasargode 400 kV D/C Line and

two bus reactor (2x125MVAr) bays at Udupi generation switchyard.

(ii) UPCL had agreed and proposed to extend the bus by providing bus sectionaliser for phase-2 expansion.

(iii) UPCL had also agreed to provide space for switchable line reactor if required.

……..

After deliberations, Members agreed for construction of already approved Udupi PCL (Mangalore) –

Kasargode 400 kV D/C Line (with Quad Moose ACSR conductor) along with Kasargode 400/220 Kv,

2 x 500MVA substation under ISTS and to drop Kasargode – Kozhikode (Areakode) 400 kV (Quad)

D/c line (with Quad Moose conductor) (Agreed in 35th

meeting of SCPSPSR)

Critical Intra-regional transmission elements

400 kV Edamon-

Kochi

286 PGCIL

32nd

TCC:

May

2018

Being monitored

under PRAGATI.

31st TCC: Line work

progressing

LILO of 230 kV

Neyveli- - Bahour at

Karaikal

32

nd TCC: April 2018


LILO of 400 kV

Bellary – Tumkur at

Pavagada

32

nd TCC: Feb 2018

400 kV Pavagada –

Hiriyur D/C line

32nd

TCC: March 2018

400 kV Hiriyur –

Mysore line

32nd

TCC: June 2018

400 kV Pavagada –

Devanahalli D/C line

32nd

TCC: December 2018

Tirunelveli (GIS) and

Tuticorin –Tirunelveli

line

32

nd TCC: March 2018

FSC at Pavagada 32nd

TCC: July 2019

18.6 Associated Transmission Evacuation Schemes in Tamil Nadu

Updated status of the following stations, evacuation schemes finalized in the 37th

SCPSPSR, which were modified in the following Standing Committee Meetings, is given

below:

Generating Station Likely COD Evacuation Status

Ennore TPS Expansion – 1 x

660 MW

2019-20

Ennore SEZ (NCTPS Stage-

IV) – 2 x 660 MW

2018-19

NCTPS Stage III – 1 x 800

MW

2019-20 41st SCPSPSR: 2019

Ennore TPS Replacement – 1

x 660 MW

2019-20 41st SCPSPSR: 2020

SEPC (1x525) October 2018 41st SCPSPSR: Require

start up power for its

Auxiliaries by April 2018.

SEPC-Thennampatty

400/230/110 kV 41

st SCPSPSR : April

2018

SEPC- Ottapidaram 400kV

(Regular evacuation)

765/400 kV, 2 x 1500 MVA

Ariyalur SS

31.3.2019 Work awarded to M/s BHEL

on 31.03.2017.

765/400 kV, 3 x 1500 MVA

North Chennai PS (GIS)

2019-20 Price bid opened on

02.06.2017 and under

evaluation.

765/400 kV, 2 x 1500 MVA

Coimbatore SS

2020-21 Administrative approval

accorded. Alternate land is

to be identified.

765 kV Ariyalur –

Thiruvalam (PG)

07.04.2018 Work awarded to M/s

Gammon India. Works

under progress.

765 kV North Chennai PS -

Ariyalur

2019-20 Tenders opened on


process.

400 kV Ennore SEZ-North

Chennai PS

Tender opened on



400 kV Ennore SEZ- Ennore

to ETPS Expn

evaluation. BLTC note for

price bid opening is sent to

Account for remarks. 400 kV ETPS Expn – North

Chennai PS

Interconnection from

common point of SEZ –

ETPS Expn to NCTPS Stage-

II and LILO of NCTPS-II –

SV Chatram 400 kV MC

between location No.21 & 22

18.7 Status of Various upcoming Lines

18.7.1 POWERGRID vide letter dated 4th

August 2017 had intimated status of commissioning

of various elements in the Southern Region. In the 32nd

Meeting of SRPC after

deliberations, it had been agreed that usefulness of early commissioning of the

transmission elements would be studied by the Study Group with participation from

constituent states, CTU, SRLDC & SRPC Secretariat. SRPC had agreed that this

Report could be approved by Chairperson, SRPC. Based in this, approval would be

communicated to CTU by SRPC Secretariat.

18.7.2 As agreed in the 32nd

Meeting of SRPC, a Special Meeting was conducted on 1st

September 2017 in SRPC, Bengaluru with participation of CTU, States, SRLDC and

SRPC. Report in this regard had been submitted to Chairperson SRPC vide SRPC letter

dated 04.09.2017. Chairperson, SRPC and CMD, TSTRANSCO had approved this

Report. Accordingly, vide letter dated 26.09.2017 (Annexure-XLV) SRPC Secretariat

had forwarded this Report to Powergrid/CTU/States.

18.8 Operational Feedback

18.8.1 NLDC vide letter dated 21st January 2018 (available in NLDC website) had highlighted

following transmission constraints as part of Operational Feedback for the quarter

October – December 2017, 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.

400 kV Udumalpet- Palakkad D/C line

31st TCC: KSEBL had stated that there was no constraint on this line. SRLDC

stated that they would examine the matter.

400 kV Hiriyur-Nelamangala D/C line

220 kV Bangalore Metro Network

Overloading of 230 kV Shoolagiri-Hosur (TN)-Yerrandahalli-Somanahalli S/C line Constraints in Nagjheri PH evacuation Constraints in Chennai 230 kV System

Overloaded 230 kV Lines in Tamil Nadu

Constraints in wind evacuation

220 kV Hyderabad Metro Network


ICT Constraints

400/220 kV 2 x 315 MVA ICTs at Gazuwaka

32nd

SRPC: SRPC had agreed in Principle for additional 500 MVA ICT and the

matter would be referred to Standing Committee by CTU for vetting.

41st SCPSPSR: After deliberations members agreed for an additional

400/220kV, 1x500 MVA ICT at Gazuwaka substation as ISTS.

400/220 kV 3 x 315 MVA ICTs at Vemagiri

31st TCC: SRLDC had informed that even after commissioning of new ICT, the

constraints persisted.

32nd

SRPC: CMD, APTRANSCO had informed that problem had reduced but

once the Mardam (Vijianagram) lines come up within two months, the issue

would get addressed.

41st SCPSPSR: APTRANSCO has to look into the issue and may plan

additional ICTs/ replacement of ICT by higher capacity.

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 1 x 500 MVA + 1x315 MVA ICTs at Narendra

400/230 kV 2 x 315MVA ICTs at Madurai

400/230 kV 2 x 315MVA ICTs at Thiruvalam

400/220 kV 3 x 315MVA ICTs at Kalpakka

400/220 kV 2 x 315MVA ICTs at UPCL

400/220 kV 3 x 315MVA ICTs at Shankarapally

41st SCPSPSR: 1x 500MVA 400/220kV transformer (4

th one) at Malkaram S/S

& Shankarpalli S/S approved

SRPC requested the respective entities to kindly identify and implement suitable short

term and long term measures to overcome these constraints in a time bound manner.

18.8.2 The following issues had been raised in OCC Meetings:

500 MVA additional ICT at Checkanoorani (Madurai) 400/230 kV S/s in PGCIL end

was commissioned on 29.12.2017. LV side 230 kV Bay work under scope of

TANTRANSCO was under progress and would be completed on 30.09.2017.

TANTRANSCO had informed that tender was opened on 16.05.2017 and would be

completed by 30.11.2017.

Completion of Kamuthi bays (2 nos) at Karaikudi

OCCM: SR-II had informed that Circuit-II was to be completed by 15.12.2017

(delay due to mis-match in the terminal equipment). Circuit-1 was expected by

January 2018 (delay was due to construction of Secured Panel Room which was

covered in ICT-III contract).

NLC ICTs

31st TCC: NLC/TANTRANSCO had been suggested to take up the upgradation

issue in the ensuing Meeting of Standing Committee on Power System Planning.

41st

SCPSPSR: TANTRANSCO had proposed a new substation at Neyveli and

with this substation the overloading issue might get resolved.

A. ICT and Bus reactors:

i) 2 x 500 MVA, 400/230 kV ICTs

ii) 2 x 125 MVAR bus Reactor


B. 400 KV Connectivity:

i) New Neyveli Thermal power station- Neyveli (TNEB) 400 kV D/C Link.

ii) Manalmedu- Neyveli (TNEB) 400 kV D/C Link.

18.8.3 PGCIL vide letter dated 09.01.2108 (refer Annexure-XXXVII) had stated that for

utilization of 1 x 500MVA, 400/220kV ICT at Trichy: Extensions of 230 kV Main and

Transfer Buses in TANTRANSCO Switchyard at Alunder 230 kV Station (Trichy SS)

under SRSS-XX are yet to be taken up by TANTRANSCO.

TCC deliberations

PGCIL (SR-II) had informed that Trichy 1 x 500 MVA ICT had been

commissioned.

18.9 STATCOM at NP Kunta

Powergrid vide E-mail dated 02.02.2018 (Annexure-XLVI) had stated that STATCOM

at 400 kV NP Kunta PS was commissioned on 04.06.2017. STATCOM being state of

the art technology product and with tight commissioning schedule of NP Kunta Phase I

generation, it had been proposed that the delivery of STATCOM be postponed

corresponding to Phase II, for which the schedule was September 2016.

TCC deliberations

TCC had agreed for commissioning of STATCOM on 04.06.2017 under Phase I. It

was also noted that this STATCOM was being utilized with Phase I generation.

It was also noted that STATCOM set points had been revised and was being

utilized for voltage regulation.

SRPC approved commissioning of STATCOM on 04.06.2017 under Phase I.

18.10 Status of transmission system for IPPs

TANTRANSCO vide letter dated 07.02.2018 (Annexure-XLVII) had intimated that

many transmission systems are evolved based on the LTOA requirements of IPPs.

Some of the IPPs entered into BPTA with CTU / TSPs had not firmed up their

generation / target beneficiaries. On account of lack of coordination among IPPs and

CTU, many of the transmission systems planned and executed had become redundant

resulting in huge impact on the financial condition of the existing DICs. Tariff

determination process had become a legal battle between the TSPs and the

beneficiaries. Further, some of the generators were approaching Hon‟ble Commission

for relinquishment of full / part LTA. This would further destabilise the planning

process and finances of the beneficiaries. Under these circumstances, it was essential

to deliberate the issues associated with implementation of transmission system

designed for IPPs. Following points needed to be brought on record and the

Committee may take a decision:

a. Status of IPPs entered into LTOA with CTU.

b. Identification and firming up of beneficiaries.

c. Operationalization of LTA quantum and sharing of transmission charges by the

defaulting IPPs


d. Progress of transmission schemes due to non firming up generation project and

non identification of beneficiaries

e. Relinquishment of LTA sought by IPPs after implementation of transmission

systems and its impact on PoC charges shared by the existing DICs.

TCC deliberations

CTU had informed that most of the information sought was available on the PGCIL

website. Some of the issues were being dealt by the Hon‟ble Commission/APTEL

etc under various petitions.

Relinquishment of LTA was being taken up as per provisions of CERC Regulations

/ CERC Orders / Approved procedure. It is well within the right of LTA holder to

relinquish LTA, while compensation/relinquishment charges would be as decided

by the Hon‟ble Commission. At times, LTA holders are relinquishing LTA at the

last moment and even some of the states are availing power from such generators.

PGCIL had been supporting the cause of beneficiaries in the relinquishment related

issues.

Many of the SR states were able to avail power from other regions at competitive

rates since the IR corridor TTC had been enhanced / released.

Most of these issues may get addressed in the proposed GNA regime. It may be

prudent to await the implementation of GNA.


18.11 Issues relating to implementation of generation projects of IPPs and associated

transmission scheme and regulatory process

TANTRANSCO vide letter dated 07.02.2018 (refer Annexure-XLVII) had intimated

that generation and transmission projects are implemented based on the approval of

Regional Power Committees. During implementation phase, some of these generation

projects and associated transmission schemes are abandoned / modified without

deliberation in the Regional Power Committees. Some of the project developers were

taking secluded action to exit from the planned schemes without knowledge of

Distribution companies who are forced to pay the transmission charges due to the

default of the promoters. Recently, the following petitions were filed by the IPPs /

TPPs/CGS without including the beneficiaries as Respondents, which would have

huge impact on the finances of the Discoms:

a. Petition No.62/MP/2017 – filed by Powergrid NM Transmission Limited for

apportionment of transmission charges among the two elements of the

transmission project viz. Nagapattinam Pooling station – Salem Pooling Station

765 kV D/c line and 765 kV Salem – Madhugiri 765 kV S/c line.

b. Petition No.164/MP/2017 – filed by IL&FS for surrender of 610 MW of LTA

c. Petition No.261/MP/2017 – filed by M/s NTPC for revision of PoC charges for

the full quantum of LTA

d. Petition No.246/MP/2016 – filed by Coastal Energen Private Limited for

relinquishment of 542 MW LTOA.


TCC deliberations

CTU had informed that due process as outlined in various Regulations/Orders was

being followed.

Most of the issues could be addressed in the GNA regime. It may be prudent to

await the implementation of GNA.

These petitions had been filed by generators against PGCIL and it was for them to

identify the Respondents. TANGEDCO was suggested to kindly file petition/IA to

implead itself in the various petitions, if so desired.

Many of these issues were already under the consideration of Hon‟ble Commission.


19 UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH

TRANSMISSION NETWORK

19.1 Status update of upcoming evacuation schemes in Southern Region for renewable as given

below is furnished at Annexure-XLVIII.

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 15 KA Gadag Wind Project Wind 90 16 KA Gadag Wind Project Wind 197 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 KA Ostro Dakshin Power Pvt. Ltd. Wind 300 49 KA Orange Ashok Wind Power Wind 250 50 KA Renew Wind Energy (TN) Pvt. Ltd.

(Koppal) Wind 400

51 TN Inox Wind Infrastructure Services Ltd Wind 500 52 TN Vagarai Suzlon wind farms Wind 200 53 TN Regen Wind Farm (Vagarai) Wind 600 or 384 54 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

19.2 The following had been noted in earlier SRPC/TCC Meeting:

It was noted that RE schemes are getting modified at times while some are getting

dropped also. TCC had suggested that the RE Projects/evacuation schemes may kindly

be reviewed and updated status 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.

It was noted that Procedure for RE Framework had already been notified and was

available at NLDC website. States/RE Developers had been kindly requested to ensure

that infrastructure to implement RE Framework either at ISTS/in STS level was in

place from the inception stage itself.

19.3 Inclusion of the transmission system for Solar Power evacuation under PoC and its

implication on CERC (Sharing of Inter State Transmission Charges and Losses)

Regulations, 2010

19.3.1 TANGEDCO vide letter dated 16.08.2017 had raised concern on huge error in

allocating transmission charges due to solar evacuation/connectivity and on the LTA


quantum of solar power parks is not being included in computation of POC charges

which leads to exemption of host state from the burden and thus, the burden is passed

on to other DICs.

19.3.2 The following had been noted in earlier Meetings:

It was noted that Hon‟ble CERC had constituted a Task Force to review,

„Framework of Point of Connection (PoC) charges‟. Terms of Reference of the

Committee covered, „Deficiency in the existing mechanism if any, and in the light

of issues and concerns of various stakeholders‟.

It had been agreed that Chairperson, SRPC would be kindly requested to take up

common issues in this regard with Hon‟ble CERC.

All DICs had been suggested to take specific issues / suggestions with the Task

Force.

19.3.3 Chairperson, SRPC vide letter dated 23.08.2017 (Annexure-XLIX) had brought out

certain issues to the notice of Hon‟ble CERC. It had been requested that Hon‟ble

Commission may kindly bestow its attention on the following issues :

Non consideration of solar LTA in arriving at the POC slab rate does not alter the

transmission charges payable by that state.

It is thus not clear in what manner or how the transmission charges waiver for solar

and wind power is to be actually implemented in the POC mechanism. This matter

merits kind attention of Hon‟ble Commission since this has implications not only

on the host state but also on the neighboring states.

Implementation of the policy regarding waiver of transmission charges merits kind

attention in view of the existing methodology of sharing of transmission charges.

19.3.4 CERC vide letter dated 06.09.2017 (Annexure-L) had informed that a Task Force had

been constituted under Chairmanship of Hon‟ble Member CERC which is already

looking in to the review of existing Framework of Transmission Charges and Losses.

SRPC letter was being referred to the Task Force for suitable consideration.

19.4 RE generator support for reactive compensation

19.4.1 In the OCC Meetings, it had been noted that even though Solar / Wind generators had

very controllable reactive injection / absorption capability, they were not being utilized

on account of PPA commitment / penalties. It had been suggested that SLDCs / STUs

may approach their Regulator for flexible set points as per direction of SLDCs. The

direction of SLDCs could be based on voltage level on season basis or on solar / non-

solar hours on daily basis. SRLDC had agreed to take up the issue in the FOR forum.

TCC deliberations

MS, SRPC had pointed out that certain provisions of PPA of solar generators may

not be as per the grid operational requirements and therefore this aspect needs to be

looked into. Hence, Reactive support/management of RE generators needs to be

examined and revisited keeping in view higher RE penetration. The

recommendation in this regard could be referred to FOR.


Director (GM), CEA had stated that in draft Amendment of CEA Connectivity

Regulations, provision of voltage set point and control of VAR interchange had

also been proposed.

TCC had opined that details could be shared by the states and the matter could be

examined to arrive at commonality in SR.


20 NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP

20.1 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 CoD from

31.07.2017

Unit-II

CoD on 31.12.2017

Unit–III

Synchronization by

Feb 2018 end and

trying to pre-pone

CoD to April 2018)

Telangana STPP

Phase I

2 x 800 32nd

TCC:

U-I CoD May2020

(Synchronization by

Mar 2020)

U-2 CoD Dec 2020

(Synchronization by

Sep 2020)

Boiler : BHEL

Turbine: Alstom

BOP: Tata Projects

Boiler columns have been

erected. Action of shifting

of the towers has been

initiated.

It was a prestigious and fast

track project.

Pudimadaka AP 4 x 1000 52 Months from Zero

Date

85% share to AP.

Zero date yet to be finalized.

AP had requested NTPC to

firm up the zero date at the

earliest.

31st TCC:

NTPC had informed that the domestic coal was yet to be tied up. Within

two months, the status would be communicated.

CTU informed that there was no connectivity / LTA application pending

with them.

NLC

New Thermal

Power Project

I 500 32nd

TCC:

April 2018

II 500 32nd

TCC:

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.

31st TCC:

Araliyur S/S being developed by TANTRANSCO was awarded to

BHEL, works were under progress and expected by March 2019.

TANTRANSCO had assured that the 230 kV system would be ready by

March 2018.

NPCIL

KKNPP 3 &

4

2 x 1000 32nd

TCC

U3: 2023

U4: 2024

41st SCPSPSR:

CTU informed that they had

not received any LTA

application from NPCIL for

Kudankulam - 3 & 4 units.

Any system strengthening

would be planned on receipt

of the LTA application based

on proper studies.

BHAVINI

Kalpakkam

(PFBR)

I 500 Synchronization by

2017-18

COD by 2017-18

31st TCC:

CTU had informed that the evacuation system was completed in 2012

and as per the CERC Order, transmission charges are to be paid by

BHAVINI. The charges were not being paid by BHAVINI and the dues

had accumulated to Rs 88 crores.

NPCIL informed that BHAVINI was a separate Corporation under DAE.

NPCIL was however kindly requested to convey the concern of CTU to

BHAVINI.

PGCIL vide letter dated 09.01.2018 (refer Annexure-XXXVII) had

stated that Kanchipuram SS of TNEB for termination of Kalpakkam

PFBR-Kanchipuram 230 kV D/C Line. TANTRANSCO had informed

that the Kanchipuram S/S would come up by December 2017 –

TANTRANSCO may confirm.

32nd

TCC:

Kancheepuram SS – TANTRANSCO informed that the S/S would

come up by March2018

UMPP

Krishnapatnam 3960

(6 x 660)

32nd

SRPC: CMD, APTRANSCO had informed that

several Meetings had been held with beneficiaries

and coastal UMPP. In the present scenario, the

usefulness of this project for beneficiaries was

limited. In the meeting it had been decided that since

the matter was pending before Delhi High Court, it

was appropriate to file a Petition for Expeditious


Hearing. However after seeking legal opinion, a

SLP before Hon‟ble Supreme Court was

contemplated seeking directions to Delhi High Court

to kindly expedite and pass Orders at the earliest.

32nd

TCC: AP informed that after discussing with the beneficiaries, an

Expeditious Petition was contemplated before Hon‟ble Delhi High Court

(before approaching Hon‟ble Supreme Court). The petition was likely to

be heard in the month of March 2018.

Cheyyur 4000 New bids would be called

21 NEW PROJECTS OF STATE SECTOR & IPP

21.1 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 2017-18

2 Dr. NTTPS, Vijayawada AP 1 x 800 June 2019

3 Krishnapatnam Stage II

(U3)

AP 1 x 800

4 Polaki AP 4000 (5 x

800 MW)

5 Edlapur KAR 1 x 800

6 North Chennai Stage III TN 1 x 800 2019-20

41st SCPSPSR: 2019

7 North Chennai Stage IV TN 2 x 800 Beyond 2019-20

8 Ennore TPS Exp TN 1 x 660 2018

9 Ennore replacement TN 1 x 660 41st SCPSPSR: 2020

10 Udangudi Stage I TN 2 x 660 2020-21

11 Uppur TPP (TBCB) TN 2 x 800 2019-20

12 Manuguru PPP Telangana 4 x 270 U1: March18

U2: June18

U3: Sep 18

U4: Dec 18

13 Kakatiya TPP Stage III Telangana 1 x 800 Not decided

14 Kothagudem TPS Phase

VII

Telangana 1 x 800 2018-19 (June-18)

15 Damaracherla (Yadadri) Telangana 5x800 U1 & 2 Nov 2020

U3 – 5 2021

21.2 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 2018-19

Untied: 640 MW

2 East Coast Energy

Thermal

AP 2 x 660

2018-19

AP : 300 MW

3 Thermal Powertech

(TPCIL) Unit-III

AP 1 x 660

2017-18


5 Godhna TPP, Janjir –

Champa Dist,

Chhattisgarh

For

KAR

2 x 800 2017-18

22 REVIEW OF ULDC / SCADA/COMMUNICATION

22.1 Status of pending items is as follows:

Issue Action plan

Frequent data outage (Central Sector)

Warangal Multiplexer problem, Spare was not available

LANCO LANCO to assure

NTPL NTPL assured that both the channels (BSNL &

PLCC) would be made healthy.

Provision of data through fiber channel: PGCIL

confirmed that the same would be made available in

the upcoming projects.

Frequent data outage (State Sector)

AP Non-availability of SAS vendor to attend / rectify the

gateway issues: an expert group for RTU/SAS issues is

under formation.

Manali

SS(TANTRANSCO)

Due to conversion of 230 kV switchyard to 400 kV level

and associated works in progress.

NCTPS Stage-2 &

Sriperumbdur SS

(TANTRANSCO)

Alternate data link from POWERTEL is under

procurement

AMC provision for SAS

gateways

Needs to be incorporated and the same needs to be

taken up by PGCIL, SLDCs and generating stations.

Data Discrepancy Constituents and Powergrid agreed to resolve by

31.10.2017.

Backup SCADA & System testing

AP Backup SLDC is planned to be established at Tirupati and

they have received an estimate of Rs. 9.90 Crores.

APTRANSCO informed that Powergrid is the consultant

for the works and have given permission to Powergrid to

give the procurement works to ALSTOM. Since the

estimate was observed to be on higher side, Powergrid

comments on the same is awaited by APTRANSCO to

move ahead.

TS Received the estimate Rs. 15.7 Crores for setting of

Backup Control Centre at Warangal of and the same is

under process. A team would be visiting LD&C, PGCIL,

Gurgaon for further deliberations.

Kerala, Tamil Nadu &

Karnataka

May be completed by Dec 2017.

KSEBL: will be carried out in first week of January 2019.

Status of mapping of

ADMS in SLDCs

ICCP between NTAMC &

RLDC

Proposal for finalizing ICCP between NTAMC & RLDC

is under review by PGCIL Management and will revert

back.

32nd

TCC:


CTU stated that they would not be interchanging data

from NTAMC through ICCP on account of cyber

security apprehensions.

It was noted that functional requirements of SRLDC

would remain and the same would be addressed by

PGCIL.

OPGW stringing on

balance portion of KPTCL

line

Except Hassan-Santhigrama (7.4 kM) OPGW stringing

completed.

Alternate connectivity to SRLDC from Somanahalli had

been made through. SRLDC had stated that they would

test the alternate connectivity.

Protection coupler

replacement for

Kayamkulam

Transmission system

SR-II: Approval for the depository amount to be paid to

KSEBL was under process.

KSEBL: Pre qualification bid opened.

Modification in EMS

package – TSTRANSCO

Had received estimate of Rs 47 lakhs and the contract

was being firmed up.

Shifting the SCADA

servers from old APSLDC

at Kavadiguda

(Secunderabad) to new

SLDC at Gunadala,

Vijayawada

APTRANSCO: Shifting completed. Operation started

from 25.12.02017

AMC for VC / UPS

SRLDC stated that they would ascertain from OEM (M/s

GE) in coordination with LD&C.

Hotline communication

for Grid operation

Equipment availability at alternate manned locations

would be made progressively and details would be

communicated by 15.11.2017(SR II).

Simplification of the

complaint management

procedure for timely

rectification of the faults

PGCIL was requested to take up the issue with M/s

Orange.

A procedure may be formulated to maintain the

monthly/weekly availability status for certification of

communication availability.

Permission for preventive

maintenance

PGCIL requested all constituents to grant the timely

permission

BOQ of SRLDC and

actual supply

To be furnished by SR-II.

Orange Exchange

integration with other

Exchange available with

TN.

SR-II stated that the details could be communicated and

wherever technically feasible, the same would be

integrated in coordination with the utility and M/s

Orange.

Problems with speech

circuits at SRLDC end

for NTPC Ramagundam,

NTPL, Vallur, NLC TS

II, NLC TS II Expansion,

LANCO Stage II, IL &

FS etc.

Whenever payments are made to BSNL at respective

ends, BSNL at other end had to inform BSNL, Bengaluru

TD for necessary updation. Copy of the bill paid could be

communicated to SRLDC.

KSEBL issues

Alternate links, SNCP

protection scheme for

KSEBL‟s network.

PGCIL to attend the issues


Issues and pending points

of Orange Exchange,

SMS Exchange & Voice

Logger.


NMS desktop operating

system – to be replaced

by Tejas.

Action from M/s BGR was required.

Remote alarm at SPS

Protection Coupler at

Madakathara


Handing over letter for

earlier ULDC

To be received from PGCIL as the final payment has been

made in June 2017.

Puducherry issues

IP phones connected with

the Hot line EPAX are

experiencing frequent

faults

POWERGRID informed that they would take up with

M/s. Orange.

Normalization of the

voice communication by

shifting the existing voice

traffic from the removed

Alcatel MUX to the

newly erected Valliant

Mux

Necessary E&M and FXO cards to be supplied for

Villianur and Bahour Auto substations; PGCIL to attend

the issue

Non-availability of

Yanam data

AP informed that the Yanam data was made through.

SRLDC stated that Puducherry could consider providing

Yanam data through a service provider (alternate route).

Talcher data 32nd

TCC: NTPC informed that there were some issues in the

communication link between NTPC to HVDC. The new

RTU was reporting to ERLDC.

SRLDC expressed concern over this long pending issue.

NTPC assured of necessary co-ordination in ensuring

SCADA data to SRLDC.

22.2 Damage of OPGW links during modification works by KPTCL.

PGCIL vide letter dated 09.01.2018 (refer Annexure-XXXVII) had stated that they had

installed OPGW on some of the KPTCL transmission lines like 220kV Bastipur-

Hootagalli, 220kV Hoody –HSR line etc (details enclosed). It had been observed that

during re-routing of 220kV Hoody –HSR line, M/s KPTCL had damaged OPGW link

resulting into loss of reliable communication for power system operation. Similar type of

incident had earlier occurred two- three times and necessary communication to M/s

KPTCL had been made requesting prior intimation to POWERGRID before

commencement of such works, so that this type of unwanted incident can be avoided.

In this regard copy of letters from SR-2 to CE (SLDC)/KPTCL, Bangalore were also

attached.

TCC deliberations

KPTCL had assured of necessary coordination to avoid such incidents in future.


SR-II had reiterated that in future whenever KPTCL takes up work it could be

informed in advance so that communication could be appropriately diverted.


22.3 Video Conferencing facility at SLDCs

Status update is as follows:

AP PUDU

Commissioned on 07.10.2017 Puducherry would take up VC

requirement in the financial year 2017-18.

23 URTDSM (PMU) PROJECT IN SOUTHERN REGION

23.1 The URTDSM Phase-I project is nearing completion. The progress is being reviewed in

the Special Meeting/OCCM. A Special Meeting was conducted on 25.10.2017 to review

the progress. The updated status is given at Annexure-LI.

23.2 PGCIL had requested all constituents to submit revised PMU requirement, if any, for

Phase-II considering availability of Wide Band nodes. KSEBL vide letter dated

28.11.2017 had submitted PMU requirement for Phase-II.

TCC deliberations

KSEBL & APTRANSCO vide letter dated 28.11.2017 & 07.02.2018 had submitted

PMU requirement for Phase-II.

NPC vide letter dated 12.02.2018 (Annexure-LII) had sought certain

information/update on implementation of PMUs and their analytics.

SRPC noted the above

24 EMERGENCY RESTORATION SYSTEM (ERS)

24.1 Requirement of ERS had been outlined in MoP letter dated 05.12.2014. CEA vide letter

dated 21.07.2017 had stated that in the Meeting held on 28.06.2017 it had been noted

that ERS were in procurement stage in most of the States and the response from the

States was not very encouraging. Secretary (Security) had earlier sought a note from

CEA to take up matter with the concerned States at the highest level. Status update as

noted in TCC is given below:

Transmission

Utility

Requirement as

per MoP

Existing Status/Remarks

APTRANSCO 3 2 ERS III would be taken up

through own funding

TSTRANSCO 1 Tender floated; would be

taken up for PSDF

funding.

KPTCL 2 2

KSEBL 1 Tenders to be floated.

Would be taken up for

PSDF funding.


TANTRANSCO 2 As per Minutes of BLTC

held on 03.01.2017,

procurement is put on hold.

Would require PSDF

funding.

PED Nil Nil

PGCIL 4 (2 Nos.

Additional)

4 (SR I &

SR II is

having 2

no. Each)

765 kV ERS (one each for

SR-I and SR-II) Order

placed. Expected by January,

2019.


25 PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR

25.1 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.

March 2018

Nelamangala Reactor erected on

platform

March 2018

Entity Bus Name

Capacit

y in

MVAR

Approved

in Type Remarks

PGCIL Yelahanka 2x63 Bus

Deferred as per 40th

SCPSPSR. When

Madhugiri line will come

it will be expedited.

Cuddapah 50 to 125 39th

SC Yet to be awarded

APTRANSCO

Vemagiri 125

36th

SC

Bus December 2017 – LOA

issued on 18.06.2017

Kurnool 125 Bus December 2017 – LOA

issued on 18.06.2017

Kalpaka 125 Bus March 2018

Chittoor 125 39th

SC APERC approval awaited

Vijayawada 125 39th

SC

It was noted that a

separate reactor at

Vijayawada in scope of

AP had been identified.

The exact location could

be firmed up by

APTRANSCO.

APTRANSCO/

APGENCO

VTPS Stage

IV 125 39

th SC

APGENCO informed that

reactor enquiry was being

taken up.


It was noted that this

reactor was different from

the APTRANSCO reactor.

KPTCL

Davangere 125 39th

SC 41

st SCPSPSR: Members

agreed with already

approved additional

reactors of 1x125 MVAR

(400kV) each at

Talaguppa and Davangere

400/220kV Substations.

Talguppa 125 39th

SC

TANTRANSC

O

Almathy 125 39th

SC Specification under

process Manali 125 39

th SC

Kayathar 125 39th

SC

TANTRANSC

O/

TANGEDCO

Mettur 125 39th

SC

To be diverted from

Palavadi and works to be

taken up.

TSTRANSCO Mamidipally 125 36

th SC

Bus

Testing and

commissioning under

progress.

TSTRANSCO/

TSGENCO Srisailam LB 125

39th

SC

41st SCPSPSR: After

deliberations, it was

agreed that TSTRANSCO

will submit the requisite

data for system study to

CTU. The CTU, after

carrying out studies will

forward the results to

CEA and TSTRANSCO.

The requirement will be

further discussed and

finalized in a Joint

Meeting.

NPCIL Kaiga 2 x 125

Bus

One reactor by December

2019.

For 2nd

reactor, NPCIL

will get in touch with

PGCIL.

UPCL Udupi 2 x 125

39th

SC

41st SCPSPSR: It was

informed that the

requirement was assessed

based on system studies,

therefore, it was decided

that the decision taken in

39th

SC Meeting may be

implemented.

SRPC requested all entities to expedite the reactor commissioning since high voltage was

being observed on sustained basis.

25.2 Commissioning of NGR bypass breaker/isolator was to be completed for the following:

400 kV Nellore-Thiruvalam line I & II, Thiruvalam-Kurnool I & II, Kozhikode-

Mysore I & II line reactors


25.3 Dynamic Compensation (Approved in 36th

SC)

Entity Bus Name

SC

MVA

GVA /

KA

Dynamic

Compensation

(STATCOM)

Mechanically

Switched

Compensation

(MVAR) Remarks

Reactor Capacitor

PGCIL

Hyderabad 18.4/

26.5

+ 200 MVAR 2x125 1x125 June 2019

Udumalpet 19.4/

28.0

+ 200 MVAR 2x125 1x125 32nd

TCC:

March

2019

Trichy 12.5/

18.0

+ 200 MVAR 2x125 1x125

25.4 Reactive Power Planning

25.4.1 Status of Capacitor installation in Transco/Discoms is given below:

Utility Reactive Power Planning Voltage

level

Remarks

APTRANS

CO

Kadapa: 273.6 MVAR

Vijayawada: 144 MVAR

Visakhapatanam:175 MVAR

On 33

kV side

28.8 MVAR commissioned

0 MVAR commissioned


APSPDCL 802 MVAR 150 MVAR commissioned

APEPDCL 276 MVAR 82 MVAR commissioned.

KPTCL Bengaluru Tr. Zone:784

MVAR

12.1 kV 30 MVAR commissioned

Bagalkot Tr. Zone: 258.1

MVAR

12.1 kV 78.3 MVAR commissioned

Hassan Tr. Zone: 150.8

MVAR


Mysore Tr. Zone: 60.9

MVAR


Gulbarga Tr. Zone: 98.60

MVAR

Nil

Tumkur Tr. Zone: 281.3

MVAR

12.1 kV 46.4 MVAR commissioned.

34.8 MVAR EI approval

awaited.

TSNPDCL 288 x 2 MVAR

110 x 1 MVAR

140 x 2 MVAR commissioned

45 x 1 MVAR commissioned

KSEBL 360 MVAR 66 kV Works will be taken up after

approval. 11kV TANGEDCO 34 x 2.4 MVAR 11 kV

16 x 2.4 MVAR 22 kV 16 x 2.4 commissioned

59 x 2.4 MVAR 11 kV IPDS tender to be opened on

30.11.2017

19 x 2.4 MVAR 22 kV IPDS tender to be opened on

30.11.2017

13 x 2.4 MAVR 110 kV PO placed on M/s Shreem

Electric Limited.

53 x 2.4 MAVR 11/22

kV

RAPDRP tender to be floated

101 x 2.4 MAVR – Erode

Region

11/22

kV

Tender to be floated.


32 x 2.4 MAVR – Vellore

Region

11/22

kV

Tender to be floated.

82 x 2.4 MVAR -

Coimbatore Region

11 kV BLTC note for price bid opening

to be submitted

822 MVAR capacitors at

Distribution level had been

commissioned out of 931

MVAR capacitors planned.

Balance 109 MVAR to be

commissioned. However, for

further enhancement of Reactive

Power, Capacitor bank

provisions have to be arranged

by Planning / Transmission

wings.

25.5 PSDF – Funding of the schemes of the state utilities for installation of capacitors

in the state network at transmission / distribution network

25.5.1 MS, Appraisal Committee & ED, NLDC vide letter dated 22.06.2016 had earlier

stated that the matter had been deliberated by the Appraisal Committee during the

Meeting held on 31.05.2016 wherein, it was decided that assessment of capacitor

requirement be carried out at regional level by engaging expert agency like CPRI.

After due approval, SRPC vide letter dated 03.05.2017 had placed work order on

CPRI for carrying out the assessment studies for Southern region (except Karnataka).

25.5.2 Base case was modeled by SRLDC & SRPC and submitted to CPRI on 23rd

March

2017. CPRI study report was received on 20.12.2017. SRPC vide letter dated

28.12.2017 (Annexure-LIII) had submitted the same to NLDC for further needful

action.

25.5.3 SRPC vide letter dated 16.01.2018 (Annexure-LIV) had also informed the states that

the CPRI Report has been submitted to NLDC and requested the states for further

necessary action at their end.


NPC had stated that there are number of schemes of capacitors from all regions.

Certain details had been further sought which could be furnished for further

processing/consideration. In a nutshell they wanted to know the capacitor available

and the capacitors in working condition. Whether earlier installed capacitors had

been considered in the study or not needed to be ascertained.

2 schemes of Telangana (total Rs 32.92 Cr) had been appraised on 25th

Oct 2017.

2 schemes of TN (total Rs 36 cr) had been appraised on 19th

January 2018.


26 NON-AVAILING OF OCC APPROVED SHUTDOWN

26.1 In OCC Meetings, it had been noted with concern that at times, entities were not

availing OCC approved shut downs as per schedule. Details of availed outages against

OCC approved shut downs (furnished by SRLDC) are given below:


26.2 In the OCCM, it was noted that SRLDC would conduct a workshop through VC

regarding importance of LC, implications on ATC/TTC/grid, IEGC provisions and

issues in postponement, deferment etc for Andhra Pradesh (Karnataka may join) &

Tamil Nadu. States had been requested to invite field officials who are dealing with

outages for the workshop. NLDC had requested that shutdowns which need approval

from other RPCs were to be submitted well in advance, since prior approval is

required from all concerned RPCs/regions. Rescheduling of approved shutdowns also

was to be intimated at the earliest for approval of the concerned RPCs / regions.

26.3 It was noted that some shutdown proposals were being requested upto the OCC

meeting day. SRLDC required a comprehensive list of all shutdowns to carryout

contingency analysis for critical elements / corridors. All proposals were to be

furnished by 3rd

of each month (for example the proposal for April 2018 were to be

furnished before 3rd

March 2018). Proposals received after 3rd

of each month would

not be considered. Any deferment or changes in the schedule needed to be

communicated in the mid review and before D-3 in the WBOCS system.

26.4 SRPC & SRLDC expressed serious concern on submission of last minute shutdown

requests (for example shutdown of Hosur-Somanahalli) and said this was needed to be

avoided in future.

Entity Aug-17 Sept-17 Oct-17 Nov-17 Dec-17 Jan-18

Availed % with respect to the OCC approved outages

AP TRANSCO 67 59 58 58 59 52

KPTCL 82 100 83 80 60 71

KSEBL NA 100 60 100 100 100

TANTRANSCO 61 69 59 75 59 78

TSTRANSCO 55 43 33 73 83 50

PGCIL, SR1 88 54 47 91 68 86

PGCIL, SR2 80 19 50 42 47 64

NTPC 100 100 100 67 86 60

NLC 100 NA NA 100 0 100

NTPL NA 0 NA NA NA NA

NPCIL 100 NA NA NA 100 NA

PNMTL 0 NA NA NA 50 0

CEPL NA NA 50 NA NA NA

MTL NA 100 NA NA NA 0

Total 73 58 51 69 61 67


26.5 SRPC requested the constituents to plan outages more diligently and increase

coordination with the field and project officials.

27 STATUS OF PHASE I AND PHASE II OF PROTECTION AUDIT

RECOMMENDATIONS

27.1 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), final Order of Hon‟ble CERC disposing of petitions had been issued on 15.12.2016.

In this Order, 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 completion of

Phase-I and Phase-II of PAR of the Constituents of Southern Region.

27.2 In this regard, based on the information furnished various Constituents, a summary table

showing the compliance status of various SR-Constituents as on 14.02.2018 is given below:

Sl.

No.

Constituent

PAR (Phase-I)

Activities

PAR (Phase-II)

Activities

PAR (Ph-I & Ph-

II) Compliance

(%)

Remarks

Stipulated

Completion Date

Stipulated

Completion Date

1 APGENCO

(Hydel) 31.12.2017 31.12.2017 66.66 Based on the status furnished,

timeline for complying with the

remaining pending

recommendations (5 in no.) is

31.03.2018 2 APGENCO

(Thermal) 30.07.2017 --- 83.33 Based on the status furnished,


remaining pending recommendations

(2 in no.) is 30.06.2018.*

3 APTRANSCO 31.03.2017 --- 98.57 Based on the status furnished, the

lone pending recommendation is

expected to be completed by April

2018.

4 TSGENCO

(Hydel) 31.03.2017 31.03.2017 91.18 Based on the status furnished,



(3 in no.) is June 2018.*

5 TSTRANSCO 31.03.2017 31.03.2017 86.36 Based on the status furnished,



(12 in no.) is March, 2018.

6 KPTCL 31.05.2017 31.05.2017 61.97 Based on the status furnished,



(27 in no.) is March 2018.

7 TANGEDCO 31.12.2017 31.12.2017 75 Based on the status furnished,



(9 in no.) is June 2018.*

8 TANTRANSC

O 31.12.2017 31.12.2017 54.54 Based on the status furnished,



(60 in no.) is December 2018.*

9 KSEBL 30.11.2016 31.12.2017 96.10 Based on the status furnished,



(3 in no.) is April 2018.


10 NPCIL

(MAPS) 31.01.2017 --- 88.89 Based on the status furnished,

timeline for complying with the lone

pending recommendation is

September 2018.

All above SR-Constituents were requested to kindly complete their respective pending PAR.

IPP‟s for whom there are pending PAR [viz., Spectrum PGL, Konaseema GPL, APGPCL

Vijjeswaram (Stage-I & Stage-II), & LANCO-Kondapalli PL] were also requested to

complete them at the earliest.

TCC deliberations

Further, all Constituents who are likely to take more time for attending their respective

PAR works, especially APGENCO (Thermal), TSGENCO (Hydel), TANGEDCO &

TANTRANSCO were requested to kindly approach Hon‟ble CERC for obtaining required

time-extensions.


28 CERTIFICATION OF AVAILABILITY OF TRANSMISSION SYSTEM OF INTER-

STATE AND RPC CERTIFIED FEEDERS

28.1 KSEBL and TANTRANSCO had requested for Availability Certificate for some of the

inter- state lines for PoC charges settlement. These lines are not fully under control of

SRLDC. It was noted that certification may be required for RPC certified lines also. A

procedure needed to be developed to certify these lines. Outages need to be verified by

SRLDC as per the Availability Certification procedure.

28.2 As agreed in the 138th

Meeting of OCC, SRLDC had prepared procedure for reporting of

the outages along with reasons. Outages and availability computation would be submitted

by the respective STUs to SRLDC for verification and subsequently to SRPC for

certification. This would commence from 01st January 2018.

SRPC deliberations

All states were requested to kindly furnish the necessary information as per this

procedure.

29 IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION

29.1 Automatic Demand Management Schemes

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

Regulatory requirements.

29.1.2 In earlier Meetings, the following had been noted:

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

for 15 minutes when frequency < 49.8 Hz.

SRLDC & SRPC had suggested that new set points at 49.9 Hz be adopted.


States had 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.

In the 31st Meeting, TCC had suggested that ADMS set points could be reviewed in

the next Meeting.

29.1.3 Number of incidents satisfying the existing logic and at logic of 49.9 Hz is given

below:

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 Ker TN TS

Aug-17 NIL NIL 48 5 1 0 6 0

Sept-17 NIL NIL 94 12 1 0 16 3

Oct-17 NIL NIL 106 4 0 0 11 0

Nov-17 NIL NIL 133 5 2 0 16 0

Frequency < 49.85 Hz for 15 Min.

and OD = Min DSM limit

Dec-17 NIL NIL 10 0 0 0 NIL NIL

Jan-18 NIL NIL 10 0 0 0 NIL NIL

29.1.4 In the 136th

Meeting of OCC, after deliberations it had been decided that the setting

would be revised to 49.85 Hz and below for frequency and for deviation of minimum

DSM limits for 15 minutes. It would be reviewed for few months and setting may be

changed to 49.90 Hz (IEGC limit) in next step. An alarm could be set at 49.90 Hz and

below for 10 minutes to enable SLDC Operator to take manual action. Also

performance/functioning of ADMS is required to be tested periodically by respective

SLDCs following the practices similar to that carried out by Kerala.

29.1.5 AP, Karnataka, Tamil Nadu and Puducherry had already implemented the revised

settings. Mock drill had also been completed by Karnataka and Kerala. Telangana and

Kerala had been requested to kindly implement the revised settings.

TCC deliberations

Kerala & Telangana agreed to implement the revised ADMS settings.


29.1.6 The following had also been noted in the OCC Meetings:

Contingency plan in respect of generation loss at pooling station level for RE.


SRLDC had pointed out that similar to existing ADMS logic (O/D), backing

down of generation during sustained U/Ds during high grid frequency may also

be required.

29.2 UFR and df/dt reliefs

29.2.1. Details of recommended, implemented, SCADA monitorable and actual relief being

realized are shown in the 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 4424 1427 4499 109 16129

% B/A 100 100 125 122 108 106 110

SCADA monitorable MW C 1650 2333 4416 1399 3915 100 13813

% C/B 59 78 100 98 87 92 85

Average Visible

Relief in August

2017

MW E 1216 1437 2497 1121 2290 77 8637

Wrt monitorable % E/C 74 62 57 80 58 77 63

Average Visible

Relief in September

2017

MW F 1215 1425 2489 1114 2280 77 8600

Wrt monitorable % F/C 74 61 56 80 58 77 62

Average Visible

Relief in October

2017

MW G 1448 878 1915 1176 2116 94 7676

Wrt monitorable % G/C 88 38 43 84 55 94 56

Average Visible

Relief in November

2017

MW H 1473 978 2724 1229 2346 95 8844

Wrt monitorable % H/C 89 42 62 88 60 95 64

Average Visible

Relief in December

2017

MW I 1347 1192 2643 1180 2270 75 9415

Wrt monitorable % I/C 82 51 74 84 58 75 73

Average Visible

Relief in January

2018

MW J 1261 1527 3139 1168 2407 80 9662

Wrt monitorable % J/C 76 66 88 83 64 80 75

29.2.2 In earlier Meetings, the following had been noted:

It was noted with concern that visible relief in Telangana, Karnataka and Tamil

Nadu was less on sustained basis over a period of time. They had been suggested to

initiate suitable steps to improve visibility. In the 138th

OCC (11.12.2017), all three

states had informed that they were contemplating additional feeders to improve

relief.


APTRANSCO had informed that out of 25 RTUs, 20 RTUs had been

commissioned and the SCADA mapping percentage had increased to 59.3 %. 5

RTUs would be commissioned shortly. For balance 30 %, a composite proposal

has been put up for PSDF funding.

TANTRANSCO had informed that additional RTUs and transducers were to be

procured to achieve 100 % SCADA mapping.

TSTRANSCO had informed that 6 RTUs had been provided for Solar Generators

and for 17 RTUs procurement was being taken up and it could take 4-5 months.

There were 18 RTUs for Interstate feeders and some would provide UFR and df/dt

relief quantum also. With this, they were likely to achieve 100 % mapping.

TCC deliberations

It was noted that both TN & Telangana had initiated steps to improve the realized

relief. There was likely to be considerable improvement by February/March 2018.

SRLDC was kindly requested to co-ordinate with TN & Telangana in this regard.


29.2.3 In the 7th

Meeting of NPC held on 08.09.2017 (refer Annexure-XXVI), it had been

agreed that each RPC would submit details/progress of feeder mapping to NPC

Secretariat. NPC had sought views of members on the review of quantum of load

shedding and stages of frequency. After deliberations, it had been agreed that there is

need for review of quantum of load shedding without introduction of additional

slabs/stages of frequency. Therefore, RPCs may deliberate on additional slabs of

frequency as well as raising the set frequency for UFR operation. These views of RPCs

would be put up in next meeting of NPC. In respect of ensuring proper functioning of

AUFR and df/dt relays, Mock test is good enough to test the healthiness of the AUFR

and df/dt relays. The frequency of site inspection was proposed to be up to six months.

RPC Secretariat shall carry out periodic inspection, in line with the provisions of

IEGC. RPC Secretariat to furnish the inspection reports to NPC Secretariat.

29.2.4 In the OCC Meetings, the following had been noted:

All states had opined that there is no need for additional slabs of frequency as well

as raising the said frequency for UFR operation.

Frequency of site inspection was proposed to be up to six months which was

agreed by all the states.

SCADA mapping validation for TS & TN to be taken up by SRLDC in

coordination with the SLDCs. The exercise to be completed within two months (by

Feb 2018). It would cover the loading (average loading as per CERC order),

clarity on radial, mixed feeders (RE), identification of new feeders to improve the

average loading etc.

TCC deliberations

All constituents had expressed concern on paucity of additional radial feeders

without overlap and also since islanding loads could not be identified for any of the


relief schemes. Being a large integrated grid, chances of fall of frequency were less

and system should be provided space for self-healing before df/dt or UFR sets in.

TCC had endorsed these decisions of OCC that there was no need presently for

additional slabs of frequency as well as raising the said frequency for UFR

operation.

Regarding quantum (based on Power Number), the SR share was being complied

as and when the same was being communicated.

It was noted that both TN & Telangana had initiated steps to improve the realized

relief. There was likely to be considerable improvement by February/March 2018.

SRLDC was kindly requested to co-ordinate with TN & Telangana in this regard.


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

29.3.1 RGMO response is being analyzed in the Meetings of OCC. SLDCs were also 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).

29.3.2 Performance of RGMO is being analyzed in the OCC forum. Summary for Southern

Region (state-wise details are given in Annexure-LV) is given in the Table below:

Hydro Thermal TOTAL

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

16.08.2017

44 45 104% 939 235 25% 983 280 29%

12.11.2017

64 2 3% 1091 340 31% 1155 342 30%

09.12.2017 (12:59)

-74 -48 65% 894 342 38% 968 390 40%

29.3.3 As per 5th

Amendment to IEGC, gas stations above 50 MW Installed Capacity were

also to come under RGMO/FGMO Operation w.e.f. 1st October 2017. SLDCs (AP &

TN and NTPC (Kayamkulam) had been requested to take necessary action to comply

with this Amendment.

29.3.4 All generators should keep a Margin for RGMO response while declaring DC in all

level ie at full load/partial load operation.

29.3.5 Special Meeting had been conducted with Tamil Nadu (25.09.2017) and ISTS

connected IPPs (27.09.2017) and actionable points are given in Annexure-LVI. VC

with Andhra Pradesh was also held on 06.11.2017 and with KSEBL on 07.11.2017.

KPTCL had joined at SRLDC on 07.11.2017. Each SLDC had been requested to

conduct Special Meetings with generators under its control area and SRLDC / SRPC

could join through VC.

29.3.6 FRC computations were also to be undertaken by the SLDCs in line with approved

methodology of CERC.



SLDCs were suggested to have periodic Meeting with generators/Discoms in their

Control Area to review RGMO performance and FRC response for the events

posted by SRLDC. Persistent non-performance needed to be taken up with the

SERCs.

NTECL Vallur had informed that they had put an alarm so that when any

FGMO/RGMO is initiated, schedule modification is suspended for some time. TCC

requested other generators to kindly consider the same.

All IPPs / MPPs to ensure RGMO margin (ensure that total schedules of LTA,

MTOA, STOA and PX are not more than the NOC (normative ex bus)). SRLDC vide

letter dated 07.02.2018 (Annexure-LVII) had addressed to IPPs/MPPs in this

regard. IPPs/ MPPs had been requested to ensure the total schedule is equal to or

less than the NOC granted. NLDC also endorsed the procedure.

29.3.8 SRPC noted the above.

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

29.4.1 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.


29.5 Sudden Change in Demand/Frequency Excursion

29.5.1 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.

29.5.2 The changeovers are being reviewed in the OCC Meetings. AP & Karnataka may need

to further stagger their changeover.



29.6 Arranging of interruptible loads in four groups

29.6.1 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.

29.6.2 Existing schemes were not meeting Regulatory requirement fully and further action

was required in this regard. Constituents had been requested to ensure necessary

compliance.


29.7 PSS Tuning

29.7.1 5th

Meeting of PSS tuning was conducted on 26th

July 2017 and MoM is available at

SRPC website. PSS Study group had analyzed the Step Response Test Reports for the

generators which had furnished the reports and recommendations had been finalized.

It had been kindly requested that necessary action may be taken as finalized in the

PSS Meetings. SRT of following units had been analyzed in the PSS Meetings 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; Lower Sileru HEP U1 AP IPP HNPCL U1 & U2 TSGENCO Nagarjunasagar HEP U1 to U8; Srisailam LB HEP U1 to U6; Kakatiya

TPS U1 & U2; Kothagudem TPS U10 & U11; Singareni Collieries

U1 &U2 (Reports to be analyzed) KPCL Raichur TPS U1,2,3,5,6,7 & 8; BTPS U1 to U3; Varahi UGPH HEP U1

to U4; Nagjheri HEP U1 to U6 (U6 report to be analyzed); Sharavathy

HEP U1,2,3,4,5,6,7,9, 10 & 8 (Report to be analyzed), Raichur TPS U4

(Report to be analyzed) KAR IPPs UPCL U1 & U2; JSWEL U1 to U3 KSEBL TANGEDCO MTPS-I U1 to U4 (U1 Report to be analyzed); NCTPS St-I U1 to U3;

Tuticorin TPS U2 to U5; NCTPS St-II U1; Kadamparai HEP U1 & U2,

Mettur-II (Report to be analyzed). TN IPPs CGS NTPC- Ramagundam U7 & 4 (Report to be analyzed); NTPC-Simhadri

U1 to U4; NTPC-Talcher STPS St-II U3 to U6; NTECL-Vallur TPS U1

to U3; NLC-Neyveli TPS II U4 to U7; NLC-Neyveli TPS II U1 to U3;

KGS U2 (Report to be analyzed); NPCIL-KKNPP U1 & U2 (Report to

be analyzed) ;NLC-Neyveli TPS II Exp. U1 & U2; (NLC & TN JV)

NTPL U1; NTPC-Kudgi U1 ISTS connected IPPs TPCIL U1 & U2 (U2 Report to be analyzed); Coastal Energen U2; IL &

FS U1 & U2


For the following Units, PSS is to be tuned and SRT to be carried out / information not

available.

Entity Generating Stations/Units

APGENCO VTPS U5 & U6; Lower Sileru HEP U2 to U4 AP IPPs TSGENCO Kothagudem TPS U7 & U8 KPCL Yeramarus TPP KAR IPPs JSWEL U4 KSEBL Idukki HEP U1 to U6 TANGEDCO NCTPS St-II U2; Tuticorin TPS U1; Kadamparai HEP U3 & U4 TN IPPs STCMS CGS NTPC-Ramagundam U1, U2, U3, U5 & U6; NTPC-Kudgi U2; NLC-

Neyveli TPS I Exp. U1 & U2 (SRT reports not submitted); NPCIL-

KGS U1, U3 & U4 ( Full Report not submitted for U4); NPCIL-MAPS

U1 & U2; ISTS connected IPPs Coastal Energen U1; Lanco Stage II & III; SGPL-Nellore; SEL U1 to

U3; MEL U1 & U2

29.7.2 SRPC urged generators to kindly initiate necessary action on the recommendations

finalized in the PSS meetings.

29.8 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.

29.9 SPS review

29.9.1 SRPC vide letter dated 06.10.2017 had requested NLDC to review the SPS schemes

for modification / disconnection etc. NLDC vide letter dated 01.12.2017 had

suggested revision in SPS for deliberation in RPC forum and approval so as to enable

the commissioning of the revised schemes / removal of schemes by CTU.

29.9.2 SRPC vide letter dated 06.12.2017 had furnished comments on the NLDC letter for

further examination. A VC was conducted on 27.12.2017 among NLDC, SRLDC and

SRPC. It was agreed that SPS 1-C, 5 & 6 would be blocked. SPS-8 will be reviewed

by NLDC. Revised logics for SPS 1-A, 1-B and 3 would be implemented. SRPC vide

letter dated 10.01.2018 had requested NLDC to expedite the SPS blocking /

modification. NLDC vide letter dated 02.01.2018 had informed that SPS-8 (outage of

765 kV Aurangabad-Sholapur D/C) was required and requested SRPC /WRPC forum

to concur for the same for implementation by Powergrid. SRPC vide letter dated

10.01.2018 had informed the concurrence of OCC. NLDC vide letter dated

12.01.2018 (Annexure-LVIII) had communicated to PGCIL for the modifications in

logic after concurrence of OCC of WRPC & SRPC. The following was noted:

Blocking of SPC-1C (S/c operation of 765 kV Raichur-Sholapur lines), SPS-5 (400

kV Wardha-Parli line), SPS-6 (400 kV Parli-Sholapur lines) was agreed considering


present system conditions to minimize chances of nuisance due to mal-operation.

SPS-4 (400 kV Raichur-Wardha) was already communicated to be blocked.

Generation backing down in Western Region may be removed from all SPS.

In SPS-1A, SPS-1D, SPS-3 & 8 the threshold of SPS operation was agreed to be

modified for the present system and network conditions.

TCC deliberations

MS, SRPC had thanked NLDC for the fast response on SPS related issues in which

three SPS were blocked while logic was modified for four SPS at the instance of

SRPC Secretariat.

It was noted that the revised logic of SPS was to be implemented by SR-I, PGCIL.


29.10 Issues related to scheduling of power

KSEBL vide letter dated 12.02.2018 (refer Annexure-XXXVI) had intimated that some

of the ISGS having multiple PPA from the same plant to the same utility (KSEBL) on

long term basis had resorted to gaming during the period of coal shortage/poor coal

quality condition. Specific cases of M/s Jindal Power Ltd and M/s Jabua Power were

taken up with SRPC and SRLDC during November 2017. As per various provisions of

IEGC, such as 2.3.1, 6.4 & 6.5, the ISGS had to furnish all relevant data to RLDC

which is to be made available to the constituents by the RLDC. This was not being

followed now. Another issue to be deliberated in this context is regarding IEGC

Regulation 6.5.19 vis-à-vis merit order dispatch. Letter dated 06.11.2017 (Annexure-

LIX) from KSEBL in this regard is attached herewith for perusal. The matter had been

taken up with CERC from SRPC, for which a clarification is expected. However, details

to be furnished by the ISGS to RLDC as per IEGC are not being furnished/collected by

RLDC even now.

TCC deliberations

KSEBL had stated that all ISG Stations (including IPPs/MPPs) are to be monitored

by RLDC as per IEGC provisions. Availability data from these ISGS (IPPs/MPPs)

is not being communicated through RLDCs for scheduling as per MOD. If total DC

of the station and DC contract-wise (different contracts may have different rates

even from same station) is furnished through RLDC, then MOD can be effectively

implemented even during coal shortage condition.

MS, SRPC had informed that some of the states had informed about difficulties

faced in real time operation on account of revision of DC during low stock of coal

or late arrival of coal rakes (for generators whose scheduling is not carried out on

percentage basis). Some generators are having multiple LTA contracts with the

states from the same unit of the station (may be at different rates). This issue was

discussed in the CC Meeting. Concern of the state had been put up for kind

consideration of Hon‟ble CERC vide letter dated 04.12.2017 (Annexure-LX) for


suitable regulatory provision which may need to be contemplated to cover cases of

revision of DC / schedule of stations under coal shortages conditions to prevent any

gaming.

MS, SRPC had further informed that the issue of DC declaration (PPA wise) of

ISGS (IPPs/MPPs) had been taken up with SRLDC vide letter dated 19.01.2018

(Annexure-LXI) in compliance of Hon‟ble CERC Order in respect of 28/MP/2016.


29.11 Restriction of DC by RLDC- Observation in AG audit

KSEBL vide letter dated 12.02.2018 (refer Annexure-XXXVI) had intimated that

SRLDC had been restricting DC of CGS considering normative auxiliary consumption

from January 2016. This matter had been deliberated in the previous SRPC Meeting

also. From June 2017, DC accepted by SRLDC for scheduling is given by SRLDC. For

the period prior to June 2017, with the available data, the difference between the DC

made by the CGS and the actual figure considered by SRLDC for allowing schedule is

related as surrender by the state. The matter has been pointed out in the AG‟s audit

during January 2018. This matter had also been deliberated in the previous OCC, CC,

TCC and SRPC Meetings. Committee may deliberate on the matter and request SRLDC

to furnish the details of the previous period.

TCC deliberations

SRLDC had stated that in the new scheduling programme the data was available. In

respect of the old data, it had to be ascertained whether the same was stored or not.

In case the old data is available, the same would be shared.


29.12 Other Issues requiring kind attention of TCC / SRPC

Following issues which are being followed up in the Meetings of Sub-Committees of

SRPC also merit kind attention:

In the 7th

Meeting of NPC held on 08.09.2017 (refer Annexure-XXVI), NPC had

emphasized need for having an accurate All India power system data base for

carrying out accurate power system studies for operational and planning horizons. It

was observed that data mining needed to be carried out for this purpose. It was

agreed that POSOCO may prepare required format and circulate to all RPCs and in

turn, RPCs may obtain data from their constituents.

In the 7th

Meeting of NPC held on 08.09.2017 (refer Annexure-XXVI), NPC had

informed that CERC had entrusted NPC to prepare Guidelines on “Availability of

communication System” in terms of Regulation 7.3(i) of CERC (Communication

System for Inter-State transmission of electricity), Regulations, 2017. In this regard,

it had been decided to constitute a Working Group with Members from RPCs,

POSOCO, CTU, CEA, PGCIL and NPC.

In the OCC Meeting, SRLDC had informed that they had received a letter from

MNRE (on Ministry of Defence request) to formulate a methodology to switch On /

Off the wind farms / Turbines near to IAF / Railways during war time using

centralized system in order to avoid any interference. SRLDC was to communicate


to states on the information sought by MNRE. They would seek clarification on

„vicinity‟ from MNRE.

All six units at Srisailam (TSGENCO) operated in condenser mode at different

times. During day time, simultaneously 4 units also were put in condenser mode.

At N‟Sagar (TSGENCO) all units (except 4 & 6) were put in condenser mode and 3

units were simultaneously put in condenser mode also.

TSTRANSCO had convened a Meeting on 23.10.2017 with L & T Metro Rail

(Hyderabad Ltd) and Discoms in which, SCADA, Operational, Telecommunication

issues etc were deliberated. TSTRANSCO vide letter dated 13.11.2017 had

communicated in this regard to L & T Metro Rail

KPTCL had implemented the 2nd

stage of UVR on 18.10.2017 for a total relief of

150 MW (50 MW in 3 stations).

PGCIL had informed that they had commissioned 400 kV, 250 MVA transformer at

Bhadravathi. The transformer was diverted from Moga.

N-1 violation of Hoody, Gazuwaka and Nellore, ICTs was noted.

CEA/NPC vide letter dated 21.12.2017/08/01.2018 had intimated schedule of

Training Program of Task-I & II of Package B being carried out by M/s Powertech

labs at RPCs. For SRPC the dates proposed were from 5th

February 2018 to 7th

February 2018.

In the 136th

OCCM after deliberations it had been decided that for planning

purposes, ISG generators would declare tentative DC (as close as possible for the

next three days). This information would be circulated in a closed group. A Google

group ([email protected]) had been created for this purpose.

SRPC had observed that there was regulation up given for the date 17.09.2017 from

03:15 hours to 06.00 hours (around 2,000 MW) and also from 05:30 to 09:30 hours

about (around 1,200 MW). Frequency touched 50.32 Hz at 06:04 hours when

Regulation up was kicked in. On scrutiny of RRAS schedule for RGPPL_IR, it was

found that down instruction was being implemented from 02:15 hours to 05:45 hours

on the same day. However, from the NLDC website, it was seen that no such

instruction appeared to have been given to RGPPL_IR. SRPC vide letter dated

20.09.2017 (Annexure-LXII) had taken up this issue with NLDC and requested to

examine the same. In the Meeting it was noted that NLDC vide letter dated

03.10.2017 (Annexure-LXIII) had replied to the same and had noted: RRAS

(Regulation Up) was dispatched from 05:30 hours to 09:30 hours on 17.09.2017 as

per prevailing grid conditions. Grid frequency increased to 50.32 Hz at 06:04 hours

and regulation up was withdrawn from 06:30 hours. It was requested that complete

sequence be seen before coming to any conclusion and mentioned that details are

already available at POSOCO website. Subsequently SRPC vide letter dated

13.10.2017 (Annexure-LXIV) had again taken up the issue with NLDC.

SRPC vide letter dated 30.08.2017 (Annexure-LXV) had brought to kind attention

of NLDC regarding RRAS schedules on Non-adherence of merit order based

dispatch and Triggering of RRAS instructions during Congestion Warning Notice

period. NLDC reply dated 13.09.2017is given at Annexure-LXVI.

Member (Planning), CEA vide letter dated 08th

September 2017 (Annexure-LXVII)

had informed TANTRANSCO that BHEL has proposed to conduct system studies


for the State Grid of TN for increasing the transmission efficiency, in view of impact

of large scale integration of renewable power in Tamil Nadu. They had also offered

to carry out these studies at their own cost as a special case. Since these studies

would be valuable for Tamil Nadu for the purpose of efficient utilization of

transmission system, this would be a good opportunity of getting these studies done,

with no cost to Tamil Nadu. CEA had also offered the services of CEA Engineers to

be associated with the study.

SRLDC had expressed concern that there is a huge gap between guidelines and

actual practice for commissioning/charging of new elements. Last minute demands

were being received for commissioning/charging of elements even though Special

Meetings and Workshops had been conducted to make constituents aware of

requirements and importance of furnishing the information in the specified format. In

a number of cases, data mismatch was observed after commissioning of the elements,

which is not rectified by them on priority after certification. The approved procedure

needs to be diligently followed.

It was observed during the BSRP workshop at Telangana that 2 nos of DG sets

available (2 x 250 KVA) at Jurala were not sufficient for starting one unit (40 MW)

and auxiliaries at Jurala for black start. SRLDC vide letter dated 13.10.2017 had

taken up the issue with TSSLDC highlighting provisions of CEA (Technical

Standards for connectivity to the Grid), Amendment Regulations, 2013 and CEA,

(Technical Standards for construction of electrical plants and Electric lines)

Regulations 2010. TSTRANSCO vide letter dated 13.10.2017 had taken up the issue

with TSGENCO and requested to arrange adequate capacity of DG set for supplying

auxiliary power supply to start the units at Upper Jurala.

TSGENCO stated that the DG upgradation may not be required at Jurala since

water is available only few months and it may not be effective for Black Start

Restoration.

It was pointed out that the requirement was as per CEA Regulation and was

needed to be complied.

Review of BSR Procedure from Nagjheri to BTPS and Jurala to Raichur TPS was to

be carried out by KAR SLDC and SRLDC.

In Review Petition No.16/RP/2016 in Petition No.10/SM/2014 filed by PCKL,

Hon‟ble CERC in its Order dated 19.12.2017 had noted „………… it can be

concluded that Karnataka was in agreement to have this LTA during deliberations of

the 24th

meeting of Standing Committee on Power System Planning…………Since

the said order dated 11.3.2013 with regard to date of COD for Hassan –Mysore line

had not been challenged by any parties before any forum, the same has attained

finality………..UPCL vide affidavit dated 29.12.2016 has stated that the delay of 16

months ( April 2011 to August, 2012) in the commissioning of Unit-2 is due to delay

on the part of PCKL whose responsibility was to ensure 400 kV lines from UPCL

switchyard. ……………However, the actual liability of transmission charges

corresponds to the LTA quantum only. In view of this, the prayer of the review

petitioners to consider LTA quantum of 421 MW instead of 939 MW cannot be

accepted and there is no error apparent in our order………………The Commission

after considering the deliberations of the meeting held on 31.3.2015 had taken a

conscious view in order dated 30.6.2016 that Karnataka would pay only the UPCL


injection PoC Charges (Rs/month) for the minimum injection slab rate for Southern

Region for the application period from 1.7.2011 to 30.4.2015. The Commission had

also directed in the said order that after the 3rd

amendment to the Sharing

Regulations, which came into effect from 1.5.2015, Karnataka would pay the

withdrawal charges……………‟.

Hon‟ble Commission in Order dated 15.12.2017 in Petition No. 184/TT/2016 in

matter of „Determination of transmission tariff for ± 800 kV Biswanath Chariali-

Agra HVDC POLE-II (1500 MW HVDC Terminal at Biswanath Chariali and Agra)

along with Earth Electrode line and Earth Electrode Station for both Biswanath

Chariali and Agra from anticipated COD1.9.2016 to 31.3.2019 under the

transmission system associated with "North East-Northern/Western Inter Connector-

I Project’ had passed the Order, „…………. 49. The petitioner shall be entitled to

recover the annual fixed charges as approved above from the DICs of all regions as

per the provisions of the CERC (Sharing of Inter-State Transmission Charges and

Losses) Regulations, 2010 as amended from time to time………….50. The petitioner

shall inform the Commission on receipt of the grant from PSDF and shall file a fresh

combined petition in respect of assets covered in Petition Nos.67/TT/2015 and

184/TT/2016 within 6 weeks from the date of receipt of the grant……………..‟

Hon‟ble CERC in Order dated 19.12.2017 in Petition No. 214/TT/2016 in matter of

„Determination of transmission tariff from anticipated COD to 31.3.2019 for 2 nos

400 kV bays each at Nagapattinam PS and Salem New (Dharmapuri) for terminating

Nagapattinam PS- Salem New (Dharmapuri) 765 kV D/C line (initially charged at

400 kV) being implemented under tariff based bidding and 1 no. 63MVAR line

reactor at Nagapattinam PS and Salem New (Dharmapuri) each for both circuits of

Nagapattinam PS and Salem New (Dharmapuri) 765 kV D/C line (initially charged

at 400 kV) under ―Common Transmission scheme associated with ISGS projects in

Nagapattinam/ Cuddalore area of Tamil Nadu- Part-A1 (b)‖ in Southern Region‟,

had passed the Order, „………Considering the surrounding facts leading to the

implementation of HCPTC XI which includes the instant asset, the decision to charge

the transmission line at a lower voltage till the demand for evacuation picks up and

the prospect of future use of the assets, the Commission is of the view that the

transmission asset shall be serviced through PoC mechanism.‟

Hon‟ble CERC in Order dated 21.11.2017 in Petition No. 71/TT/2017 in matter of

„Petition for determination of transmission tariff from DOCO to 31.3.2019 for 400

kV Salem PS (Dharmapuri)-Salem 400 kV D/C quad line along with new765/400 kV

pooling station at Salem (Dharmapuri) (initially charged at 400 kV) and bay

extensions at Salem 400/220 kV existing sub-Station under transmission system

associated with common system associated with CEPL and Ind-Bharat Power

(Madras) Limited LTOA generation projects in Tuticorin area- Part-B" in Southern

Region‟ had passed the Order, „………It is observed that the instant asset is put to

use since Salem Pooling Station is connected to existing Salem (400 kV) Sub-station

and to Nagapattinam Sub-station. The instant assets form part of the meshed

network. Therefore, the transmission charges associated with the instant assets shall

be recovered through PoC mechanism. The issue raised by TANGEDCO is that it

will have to bear entire transmission charges because only it has PPA for 558 MW.

Post notification of 2010 Sharing Regulations, 2010, no asset is bilaterally billed


once it is put under PoC pool and it is being borne by the beneficiaries/DICs who

are using the asset. Hence, concerns of TANGEDCO are addressed.’

Hon‟ble CERC in Petition No. 235/TT/2016 in matter of „Approval of transmission

tariff of Tuticorin PS -Salem PS 765 kV D/C line (initially charged at 400 kV) along

with Bay extensions at Salem PS and Tuticorin PS and 80 MVAR Line Reactors at

each end of both circuits of Tuticorin PS-Salem PS 765 kV D/C line (initially

charged at 400 kV) (COD: 13.11.2016) under “Transmission System associated with

Common System Associated with CEPL and Ind-Bharat Power (Madras) Limited

LTOA Generation Projects in Tuticorin Area-Part-B” in Southern Region from COD

to 31.3.2019 ……………………‟ vide Order dated 19.09.2017 had stated, „87. We

have considered the submissions of the respondent and the petitioner. Neither

TANGEDCO nor the petitioner has denied the quantum of 558 MW LTA being

operated against the total LTA capacity of 2000 MW. The transmission line (765 kV)

has been charged on 400 kV level which is sufficient to carry power for CEPL and

utilization of transmission capacity. It is noticed that the asset covered in the instant

petition is put to use since Salem Pooling Station is connected to existing Salem (400

kV) Sub-station and to Nagapattinam Sub-station. The asset forms part of the

meshed network, therefore the transmission charges associated with the assets

covered in the instant petition shall be recovered through PoC mechanism.‟

TPCIL had filed a Petition No.193/MP/2016 in the matter of „Petition under

Regulation 6.5(17) of the CERC (Indian Electricity Grid Code) Regulations, 2010

(Grid Code) …… seeking a direction to the respondents to act pursuant to the Grid

Code and carry out consequential steps post declaration of Grid Disturbance‟. In

the Order dated 19.12.2017, Hon‟ble Commission had stated, „……..30. We hold that

the provisions of Regulation 6.5.17 are attracted in present case since the event is a

grid disturbance………31. However, we observe that Regulation 6.5.17 of the Grid

Code requires certification of grid disturbance and its duration to be done by the

concerned RLDC. Accordingly, we direct SRLDC to certify the event under instant

Petition. On the “period affected by grid disturbance” we have passed directions at

Para 47 of this Order……32. We observe that Regulation 6.5.17 also provides that

scheduled generation of „all the ISGS‟ present in region has to be revised to their

actual generation. We note that there may be an event which does not affect all ISGS.

The words „all the ISGS’ should be read as „all the affected ISGS‟, since revision of

schedule should not be carried out for the ISGS which are not affected by particular

grid disturbance………37.....Once an incident is categorised as “grid disturbance”

as per The CEA (Grid Standards) Regulations, 2010, the provisions of Regulation

6.5.17 of the Grid Code is applicable. RLDCs and RPCs are directed to provide

historical data where each regulation (6.5.16 or 6.5.17) was applied within three

months of issue of this order. On receipt of this data from RLDCs and RPCs, we also

direct the staff of the Commission to analyse the applicability of Regulation 6.5.16

and Regulation 6.5.17 under different circumstances and propose draft amendment

to the Grid Code, if required…….45. Hence, the schedule should be revised to actual

for power supplied under Long term/ medium term for the period affected by grid

disturbance. After certifying the “period affected by grid disturbance” as already

directed, the DSM charges be revised accordingly for MTOA……48.The Commission

is in the process of finalizing the draft procedure submitted by NPC. Once the draft

procedure as submitted by NPC is approved by the Commission, the accounts related

to bilateral short term transactions and power exchange transactions of the present


case shall also be settled as per that procedure.‟

SRLDC vide letter dated 24.01.2018 had certified that tripping of 400 kV Nellore

Pooling Station – TPCIL line and 400 kV Nellore Pooling Station – NCC line

leading to tripping of TPCIL units on 30.12.2015 (06:02 hours to 07:17 hours is

certified as Grid Disturbance

SRPC had accordingly revised the account.

In Petition number 88/MP/2016, Hon‟ble CERC vide its Order dated 05.12.2017 had

stated, „……21. In case, the generator has constructed its dedicated line and

commercial billing is being done at interface with ISTS i.e. at termination point of

dedicated line, check meter shall be installed in addition to main meter to ensure

that in the event of mal-operation of main meter, the data could be retrieved through

check meter………25.We are constrained to state that not providing data by PGCIL

for the aforesaid period is untenable and would not be tolerated in future.‟

Hon‟ble CERC in Petition No. No. L-1/225/2017/CERC in matter of „Terms and

conditions of tariff for the tariff period starting from 1.4.2019- Seeking of

information from Central Generating Companies, Joint Ventures Companies,

Independent Power Producers and Central/Inter-State Transmission Companies

whose tariff is being regulated by CERC‟ vide Order dated 10.11.2017 had sought

certain information as the Commission intends to start the process of finalizing the

Terms and Conditions of Tariff Regulation for the tariff period commencing from

1.4.2019.

NTPC had filed a Review Petition No. 44/RP/2016 in Petition No. 236/MP/2015 in

matter of „Review Petition ………. in Petition No. 236/MP/2015 passed by the

Commission‟. Hon‟ble Commission had passed the Order on 17.10.2017 in respect

of KTL and other issues.

PGCIL had filed a Review Petition No. 42/RP/201 in Petition No. 236/MP/2015.

Hon‟ble Commission in Order dated 11.10.2017 had stated, „… Since Narendra sub-

station was part of Kudgi TPS and the Petitioner delayed in achieving COD of the

sub-station, it is required to pay the transmission charges to KTL….. Therefore, the

Review Petitioner becomes liable for payment of transmission charges to KTL for the

period 24.8.2015 till 11.12.2015. To this extent, the impugned order shall stand

modified……. 23. We are of the view that there is no patent illegality or error in

directing CTU to raise the bills for transmission charges for payment to KTL.‟

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 & SRPC had stated that Point to Point Black Start mock exercise needs to

be given more importance and completed twice a year.

Comprehensive award scheme for the year 2016-17 details to be furnished by STU

(through SLDC) to [email protected]. Details of PGCIL and ISTS licensees to be

furnished to SRPC (through SRLDC) and to [email protected]. These details need to

be furnished by 15.03.2018. The details had been communicated in the OCC

webgroups.

SRPC requested the concerned entities to kindly take necessary action and ensure

compliance.

mailto:[email protected]


30 IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT

SYSTEM (PMS) FOR SOUTHERN REGION

30.1 In pursuance of the recommendations of Task Force on Power System Analysis under

Contingencies constituted in the aftermath of Grid Disturbances in July, 2012, SRPC in their

26th

Meeting held on 20th

December, 2014 at Visakhapatnam, had approved a proposal to

procure Protection Suite (Protection Management System - PMS) that comprises Web-based

Management Software and Protection Setting Calculation Tool through PSDF funding.

Subsequently, steps had been taken to get the scheme approved from PSDF, and Sanction

Order in this regard had been received vide MoP letter no: 10/1/2014-OM dated 02.01.2017.

Based on this, tender for executing the Project, “Procurement of Web-based Management

Software and Protection Setting Calculation Tool for Southern Region”, had been invited

through open bidding process from qualified and reputed bidders through SRPC tender

notification dated 23rd

March 2017. After evaluation of the received bids (technical &

financial), the project had been awarded to M/s PRDC Pvt. Ltd. (PRDC) on 09.08.2017. The

execution period for the Project is about 18 months from the date of placement of LoA (also

called “Effective Date”), and is followed by an Extended Technical Services period of 5

years.

Detail of the project implementation including Milestone-wise status is given at

Annexure –LXVIII.


MS, SRPC had informed that M/s PRDC had imparted training during November /

December 2017. The data centre had been set-up in SRPC and had been inaugurated

during the last PCSC Meeting held on 31st January 2018. He had thanked all the states for

the kind cooperation extended in this regard.

TSTRANSCO had requested for data collection for stations at 132 kV also. SRPC

Secretariat clarified that as also noted earlier, collection of data for stations one voltage

level below 230/ 220 kV was not under scope of the project. However provision had been

made to ensure modeling of the Sub Stations including Wind/ Solar Pooling stations at one

voltage level below 230/ 220 kV (132 kV in AP & TS, 110 kV in Tamil Nadu &

Puducherry, 66 kV & 110 kV in Karnataka & Kerala) by PRDC provided required data for

these stations is collected and furnished by concerned Constituents (STU‟s) as per the

stipulated formats. Further, it may please be noted that data collection & modeling of all

varieties of Generators (Coal/ Gas/ Hydro/ Liquid Fuel/ CPP/ Cogen/ etc.) at 132/ 110/ 66

kV voltage level will be taken up by PRDC.


31 COMPLIANCE STATUS OF NEW PROTECTION AUDIT

RECOMMENDATIONS

31.1 As part of GSC (Task-II) under Package-A, protection audit check of 15 stations was

carried out by M/s Tractebel Engineering (TE) in Southern Region during the period,


December, 2015– July, 2016, when certain recommendations were also given for each of

these stations for compliance.

31.2 Subsequently, protection audit of various stations in SR is also being regularly conducted

by SRPC teams in line with CERC Order dated 27.04.2015 in respect of APTRANSCO

Petition No.95/MP/2015 dated 09.04.2015. So far, protection audit of 9 stations were

carried out during the period December, 2016 – February, 2018, when certain

recommendations were also given for each of these stations for compliance. Details of the

stations audited during the period September 2017 – February 2018 are given below for

kind reference:

Status of implementation of the remarks given for all above stations was reviewed in the

71st Meeting of PCSC held on 31.01.2018. It was noted that while majority of the remarks

had already been attended, specific time-frame for complying with pending remarks was not

provided. Accordingly, the following was agreed:

W.r.t. those pending remarks where no procurement action is involved, concerned

Constituents would take necessary steps to attend & complete the same by 15.03.2018.

W.r.t. balance pending remarks, concerned Constituents would take measures to attend

and complete the same by June, 2018.

Remarks which require longer time-frame than June, 2018 would be given target

timeline along with suitable course of action to accomplish the same.

TCC deliberations

APTRANSCO, TSGENCO, TSTRANSCO, KPCL, KPTCL, KSEBL, TANTRANSCO,

Puducherry ED,NTPC (RSTPS), NPCIL (KGS), NLCIL, PGCIL (SR-I) & PGCIL

(SR-II) were requested to take suitable action to comply with the pending remarks.


32 AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE

TRANSMISSION LINES OF SOUTHERN REGION

32.1 It is common knowledge that majority of the 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.

32.2 Provision for Auto-Reclosure is also mandated by Regulation 43 (4) (c) of CEA Technical

Sl. No. Name of the Station

Audited

Period of Protection

Audit

Composition of Audit

Team

1 220 kV Sharavathy

Generating Station of KPCL

30-31 October, 2017 SRPC, SRLDC & KSEBL

2 Both sides of 400/ 220 kV

Kozhikode SS of PGCIL

(SR-II)

21-22 December, 2017 SRPC, SRLDC, KPTCL &

KSEBL

3 Both sides of 765/ 400 kV

Maheshwaram (GIS) SS of

PGCIL (SR-I)

8-9 February, 2018 SRPC, SRLDC &

TSTRANSCO


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.

32.3 In this connection, status of A/R implementation by SR-Constituents on their 220 kV &

above transmission lines in SR-grid and the action plan proposed for implementing A/R

where it is presently not in service was reviewed in the 71st Meeting of PCSC held on

31.01.2018. The details are given at Annexure-LXIX.

32.4 From the details furnished by various Constituents, it is noted that the main issues in

implementing A/R are the adopted conservative protection philosophies, lack of proper PLCC

communication, and breakers‟ suitability/ supportability. Hence, it is intimated that if there

are no issues w.r.t. carrier communication and breakers’ supportability, concerned

Constituents shall make efforts to implement A/R immediately in their respective networks.

Where communication & breaker related issues stand in the way of implementing A/R,

concerned Constituents shall take steps to address them appropriately on priority basis, and

implement A/R in their respective networks in a phased manner at the earliest.

TCC deliberations

All concerned Constituents [APGENCO (Hydro), APGENCO (Thermal), APTRANSCO,

TSGENCO (Thermal), TSGENCO (Hydro), TSTRANSCO, KPCL, KPTCL, KSEBL,

TANGEDCO, TANTRANSCO, NPCIL (KKNPP), NPCIL (MAPS), NLCIL, UPCL &

JSWEL] were therefore requested to kindly take action accordingly to implement A/R on

their lines as per the committed timelines.


33 PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS

33.1 Insulator tracking had been observed in Transmission lines and Substations located in the

coastal and polluted areas. 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.

33.2 Concerned entities need to kindly initiate/continue necessary steps to ensure that

Patrolling and Maintenance is carried out regularly as per the Patrolling Guidelines.


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

– IN RESPECT OF LVRT AND OTHER PROVISIONS OF CEA/CERC

REGULATIONS

34.1 Four 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.

34.2 Quarterly reports of the SR constituents jointly validated by SRLDC/SRPC Secretariat

were being 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.

34.3 CEA had issued draft second amendment in CEA (Technical Standards for connectivity

to the Grid) Regulations. The final notification is awaited.


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. SLDCs were requested to approve connectivity to new

generators only on confirmation of availability of LVRT feature and other

CEA/CERC requirements. Monthly report of compliance needs to be furnished for

new wind/solar generators added to the grid.

SRLDC had pointed out that PMU at Pooling station was required to assess LVRT

performance.

SRLDC had requested that SLDCs may kindly prepare a geographic picture of the

Wind/Solar generators and extend it to SRLDC through ICCP. Later it can be

integrated to Regional Picture. In the REMC project extension of data was to be

carried out by states and action now would make it easier subsequently.

34.5 The 4th

meeting on LVRT / RE issues was held on 25.10.2017 (Minutes available on

SRPC website). Number of actionable points had been finalized in the meeting. SRLDC

vide letter dated 29.11.2017 (Annexure-LXX) had requested the entities to take necessary

action and resolve the issues within the time line mentioned. Following issues were

highlighted:

Submission of WTG data by all states as per the format circulated by SRPC / SRLDC

within one week.

Inclusion of suitable clause in the bidding documents (Solar) to ensure LVRT

compliance and provide details of NITs issued after the date of CERC Order.

Identification of optimal location for installing PMUs for LVRT analysis purposes.

Conducting capacity building workshop regarding forecasting and scheduling of RE.

STUs were requested to study the line loading in the systems for M-1 compliance and

submit report to CEA.

Identify and implement „Contingency Demand Disconnection Scheme‟ for locations

having large chunk of RE generation to the tune of 1000 MW and above.

All states were requested to analyze Solar generation ramp-up / ramp down based on

the capacity and identify the measures for compensating the same.

States were requested to take up the issue of PPA provision related to MVAR

interchange with respective SERCs for modifying the same to mitigate high voltage

scenario in the grid.



SRLDC & SRPC Secretariat had expressed concern that the requisite information / data

was awaited from most of the entities.

TCC had noted the above and suggested that necessary information as requested by

SRLDC vide letter dated 29.11.2017 be furnished at the earliest.


35 REVIEW MEETING ON COMPLIANCE OF PCSC RECOMMENDATIONS

35.1 Monthly Meetings of PCSC are being conducted to discuss from among other things, the

previous month‟s trippings with a view to identify their root cause and scrutinize the

correctness of operation of protection systems put in place by the concerned Constituents.

In the process, appropriate measures required to be taken for system improvement are

also being suggested/ recommended for compliance by concerned Constituents.

35.2 These PCSC recommendations, which are yet to be complied with, are being circulated

regularly vide Agenda & Minutes of PCSC meetings. However, in view of delay in

complying with them, a Review Meeting was also held on 18 – 19 December, 2017 at SRPC

Secretariat, Bengaluru to ascertain their current status of implementation by various

Constituents. Based on these deliberations held, the detailed status of pending

implementation of PCSC recommendations had been compiled and circulated to all SR-

Constituents vide SRPC letter dated 03rd

January 2018. It had been requested that concerned

Utilities take concrete and definite action in complying with the pending PCSC

recommendations.

35.3 Further, the following specific issues were also highlighted for necessary action by

respective Constituents:

Implementation of Line Differential Protection (as both Main-I & Main-II) in Nellore

Complex & Simhadri Complex:

Nellore Complex Constituents responsible for

LDP implementation

Agreed Time-line for LDP

implementation

Line Differential Protection

(LDP) to be implemented on

all 400 kV lines (< 50 km)

PGCIL (SR-I), TPCIL & SGPL March, 2018

APGENCO & APTRANSCO April, 2018

MEPL & SEL As and when their financial

healthiness improves

Simhadri Complex Constituents responsible for

LDP implementation

Agreed Time-line for

LDP implementation

Line Differential Protection

to be implemented in

Simhadri Complex on all

400 kV lines inter-

connecting Gajuwaka SS,

Kalpaka SS, Simhadri STPP

and Hinduja TPS

PGCIL (SR-I) & NTPC

March, 2018

APTRANSCO & HNPCL April, 2018


Implementation of Auto-Reclosure (A/R) on all 220 kV & above transmission lines:

Detailed logics for implementing A/R had been finalized in various PCSC meetings. It

was requested to kindly ensure that A/R is implemented on all 220 kV & above

transmission lines as per agreed logics at the earliest.

KPCL specific Issues:

It was noted that to comply with various PCSC recommendation, a DPR covering stations

such as Kadra, Kodasalli, Gersoppa and Raichur TPS for providing (i) double-bus

operation, (ii) numerical bus-bar protection, (iii) numerical relays for Generator

Transformers (GT‟s) and left-out transmission lines, and (iv) new breakers & isolators has

been prepared and is under approval stage from KPCL Management. It was also noted

that these works are proposed to be executed with funding from PSDF in a time-frame of

two-years.

Since providing of above had been pending for a couple of years, and are important from

protection perspective, KPCL was reminded of the urgency of the works, and requested to

take concrete action for early implementation.

KPTCL specific Issues:

Attending protection works at 220/ 110 kV Ambewadi SS: Ambewadi substation of

KPTCL is an inter-regional substation located on the north-western periphery of

Karnataka. The criticality of the substation can be gauged from the fact that not only does

it form an important outlet for evacuation of power from 220 kV Nagjheri PH, but also

constitutes the vital link in supplying power to the tune of (100 MW) to the state of Goa

located in western region. Given its significance, this substation was audited by SRPC

team way back in 2012, which recommended certain actionable measures covering

several protection aspects including reviewing earthing of all equipments for

implementation. Similarly, there was an internal-audit of the substation conducted by

KPTCL in April, 2014 with regard to strengthening of earth-mat. Then in April, 2015, a

field visit of the substation was undertaken by CEA team to ascertain the problems in the

transmission lines feeding Goa from Karnataka in Southern Region, which gave certain

protection-specific recommendations to be implemented at Ambewadi S/S to improve

export capacity of 220 kV Ambewadi - Ponda lines. Apart from these, there are also

recommendations specific to Ambewadi SS given by the Protection Coordination

Sub-Committee (PCSC) of SRPC w.r.t. providing bus-bar protection, LBB protection,

double-bus operation, and auto-reclosure on all lines emanating from Ambewadi.

In this regard, status of protection audit works and implementation of PCSC

recommendations was reviewed in the Meeting when KPTCL informed the following:

R&M of Ambewadi Substation was awarded by KPTCL prior to the protection Audit. So,

additional works which have to be taken up for complying with protection audit

recommendations like providing M-II for 220kV lines, GPS time synchronisation etc

were added to the scope of R&U while preparing the DPR for the project . Later, due to

poor response of M/s ERL, the R&M was short-closed by CEE, TZ, Bagalakot.

Considering the importance of the substation, it was planned to include the left out

works of R&M to the extended scope of R&U project. But considering the huge variation


and its commercial implications, management disallowed the additional works proposed

at Ambewadi and allowed only the original DWA Scope of work under R&U. Due to the

circumstances mentioned above, none of the protection audit works could be executed at

Ambewadi.

A site Meeting was planned during December, 2017 to discuss about further plan of

action for attending SRPC recommendations pertaining to the Substation.

Subsequently, KPTCL vide their mail dated 09.02.2018 intimated that CEE, RT and R&D

had visited Ambewadi S/S and conducted a site Meeting with CEE, TZ, Bagalakot and

other officials concerned on 11.01.2018 to discuss about further course of action. During

that Meeting majority of the Officers present opined that new bays can be created in the

available future bays in the station instead of spending time and money on up-gradation

works in the existing bays in service, due to the following reasons:

a) Existing 220 kV station structures are in deteriorated condition and require urgent

replacement.

b) To execute R&M works envisaged earlier lot of shut downs are required which are

difficult to avail considering inter-state connectivity with the State of Goa and

connectivity to Generating Stations.

c) Execution of R&M works consumes lot of time owing to both Line clear and

safety precautions that are required to be taken during LC works. Most of the turn

key contractors are not prepared to take up such works which involves risk.

d) Due to the above reasons, the responses from bidders for R&M works are

generally poor owing to very nature of the work which is primarily that of

repairing the existing system.

e) Cost involved in putting up a new substation may not be much as existing Power

transformers can be utilized in the very same substation. And nevertheless, the

time gained in putting up a new substation without causing any interruptions either

to Generation or load vis-à-vis the time lost and interruptions caused in carrying

out R&M works would offset the extra expenditure which may be incurred. The

other released materials can be utilized elsewhere wherever required.

In view of the above advantages, proposal for a new 220 KV substation either with

Hybrid or GIS considering space availability for the switch yard, reorientation of lines

and the scheme to be adopted for the switchyard is placed before the management for

consideration and approval.

On this, SRPC stated that setting up new 220 kV GIS/ Hybrid Substation in the available

space at Ambewadi constitutes a long-term solution involving an incubation time of about

2 to 3 years; whereas attending protection audit remarks is an immediate requirement

pending from 2012 (time-line given by Hon‟ble CREC for the same was 31.05.2017).

Further certain works like earth-mat strengthening are needed to be taken up urgently

irrespective of whether their proposal for new station gets nod from their management or

not. As such, KPTCL was requested to attend to pending protection audit remarks on

priority basis without linking them with their new station proposal. 35.4 SRPC noted the above and suggested the concerned entities to close the pending

points/issues.


36 COMMERCIAL COMMITTEE ISSUES

36.1 Following issues were brought to the kind attention of TCC/ SRPC:

Outstanding payments to DSM pool account as on 15-02-2018 as interest payable

due to delayed weekly charges

Sl.

No. Beneficiary Interest payable (Rs)

SRPC

account issue

date

1 AP

16660 08-09-2017

2 7458 10-10-2017

3 Telangana 6973 15-11-2017

4 CEPL 9156 09-01-2018

5 KKNPP* 1725 08-07-2016

6 MEL

3654 13-12-2017

7 9384 13-12-2017

8 SGPL 13632 09-01-2018

* KKNPP payment is due since July, 2016 and KKNPP is not a participant in the DSM pool now

(after COD of Unit 2).

Delay in SEM data transfer

CC Forum had been continuously requesting SR constituents to furnish SEM data

in time to SRLDC, and impressed upon all concerned the effect of the delay/non

availability of data on the accounting and possible losses. There were instances of

notable delay or non-receipt of SEM data as illustrated below for the period from

23.07.17 to 08.10.17:

Andhra Pradesh No of

Instances

Karnataka No of

Instances

AP Carbides 12 Bellary Pooling Station 8

Brahmanakotkar 12 Kadra 12

Chillalallu 12 Raichur 10

Chittoor 12

Kurnool 12 Kerala

Lower Sileru 12 Manjeswaram 6

Piduguralla 12

Ragulapadu 12 Puducherry

Tallappally 12 Villianur 12

Tangeda 12

Upper Sileru 12 Tamil Nadu

Uravakonda 12 Alamathy 12

VTPS 12 Gummidipundi 12

Kamavarapukota 12 NCTPS 12

STCMS 12

Hosur-TNEB 10

Karamadai 8

ISGS

MAPS 12

BHAVINI 12


Status of Start-up power drawl, Infirm injection and CoD Declaration

Start Up Power

Sl.No Generator Startup power granted

From To

Nil

Infirm Power

Sl.No Generator Infirm

Injection

started from

6 month period

would end by

Extension

granted by

CERC

1 Kudgi U-3 22-08-16 21-02-18 NA

(Advance action may be taken in the likelihood of delay in declaring CoD beyond

6 months)

PSDF Transfer

Status of fund transfer from SR to PSDF as on 21.11.17 is as given below:

(In Rs. Crores)

UI/DSM A/c.

(Including

capping A/c.)

Reactive

A/c.

e-bidding

charges

Congestio

n Amount

Grand Total

Total (Up to

May'17) 1369.10596 3.7940429 561.584595 2.41198 1936.89658

Aug'17 50.00 0 0 0 50.00

Total (Upto

Sep‟17)

1419.10596 3.7940429 561.584595 2.41198 1986.89658

No amount is being transferred to PSDF from DSM pool account on regular basis

in order to keep sufficient surplus funds to meet RRAS deficit in pool accounts of

all RLDCs. An amount of Rs 15.8605 Crore was transferred to NRLDC deviation

pool account on 04.10.2017.

Transmission Charges pertaining to Kudgi STPS

In the 36th

Meeting of CCM, SRPC Secretariat had informed that the RTA accounts

for the months of August and September 2017 was initially issued indicating the

transmission charges in respect of NTPC Kudgi payable by beneficiaries and

subsequently the RTA was revised indicating the Kudgi transmission charges

payable by NTPC (Generator) as per Sharing Regulations.

CCM had opined that Revised RTA is in order and NTPC was liable to pay the

transmission charges as shown in RTA. NTPC had subsequently approached

Hon‟ble CERC with a Petition in this regard.

It was noted that with installed capacity of 2,400 MW and Normative Auxiliary

Consumption of 5.75 %, the ex-bus capability of Kudgi STPS works out to only

2,262 MW. Accordingly the LTA quantum needed to be revised. NTPC (LTA

applicant) had been requested to kindly approach CTU for revising the LTA

quantum by relinquishing excess LTA quantum of 130.49 MW. SRPC vide letter

dated 03.01.2018 had taken up this issue with NTPC. NTPC vide letter dated


02.01.2018 (Annexure-LXXI) had taken up the issue of LTA revision to 2,262

MW (against granted LTA of 2392.49 MW) with COO, CTU.

TCC deliberations

NTPC had stated that the relinquishment/revision of LTA for Kudgi STPS was to be

applied by the beneficiaries (NTPC letter dated 07.02.2018 is at Annexure-

LXXII).

Beneficiaries had opined that LTA application was furnished by NTPC and hence

relinquishment application also needed to be furnished by NTPC. NTPC stated that

in the PPA, it is clearly specified that NTPC would be applying LTA on behalf of

the beneficiaries.

CTU had stated that request for relinquishment was required either from the

beneficiaries or from NTPC for further processing at their end. It was suggested

that it was in the interest of the applicant (beneficiaries / NTPC) to request for

relinquishment at the earliest since billing was being carried out as per LTA

operationalized. Relinquishment charges would be as per the Order in Petition

No.92/MP as and when it is passed.

Special Meeting would be held to sort out the relinquishment of LTA issue. CTU

was requested to kindly ensure its participation in that Meeting.


Drawal from ISTS by Generators not scheduled/getting dispatched and not

having ISTS access

SRPC Secretariat had informed the forum that some of the generators, connected to

ISTS, in Southern Region do not get dispatch schedule for long time. Some of the

generators do not have ISTS access also. However, such generators draw power

from the grid almost continuously.

Such drawal are accounted in the DSM, which may need to be reviewed. SRLDC

had been requested to kindly seek the opinion of NLDC in this regard.

Methodology procedure for computing actual drawal / injection

Methodology / procedure for computing actual drawal / injection of entities in case

of non-availability of main / check / standby meter data was discussed in the 7th

Meeting of NPC held on 08.09.2017 (refer Annexure-XXVI). After deliberations, it

had been agreed that the actual loss on the line or ICT computed based on the

previous week data may be used for loss application (in case of non-availability of

previous week data nearest week available data may be used). The same should be

implemented from first week of December 2017). It was decided that NPC

Secretariat may develop a framework for replacement of meters after taking inputs

from RPCs on the practice being followed by the utilities.

Implementation of 5 minutes scheduling, metering, accounting and settlement

Implementation of 5 minutes scheduling, metering, accounting and settlement was

discussed in the 7th

Meeting of NPC held on 08.09.2017 (refer Annexure-XXVI).

After deliberations, NPC had noted that RPCs if so desire, may discuss the issue at

their level. It was noted that Regulators had constituted a sub-group with adequate

representation from all stake holders and the ToR includes five minutes scheduling,

metering, accounting and settlement.


Simhadri Stage-1 LTA-arriving the slab rate for Telangana

SRPC vide letter dated 02.01.2018 (Annexure-LXXIII) had taken up the issue of

inclusion of Simhadri Stage-1 LTA in the POC slab rate with NLDC.

Removal of 18.5 MW of untied power of UPCL from RTA

In line with Hon‟ble CERC Order dated 23.08.2017 in respect of Petition No

242/MP/2016, all the RTAs stand revised by removing the quantum of 18.5 MW of

untied power pertaining to UPCL (SRPC letter dated 04.01.2018 in this regard is

enclosed as Annexure-LXXIV.

Pending payments between WR& SR Constituents as on 23.10.2017 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 GUVNL Nil

Kerala MPPMCL 1,21,47,260

CSPDCL 7,05,279

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

* In the Meeting of SR-WR held on 09.11.2016 at WRPC, Mumbai, MPPMCL had

informed that it had to receive payment from APTRANSCO and the details would

be shared with APTRANSCO/SRPC Secretariat.

TANTRANSCO vide letter dated 28.12.2017 (Annexure-LXXV) had taken up the

issue with MS, WRPC requesting that necessary arrangement may please be taken for

TNEB to receive the amount of Rs. 1,17,17,268/- from MPPCL and the amount of Rs.

29,80,994/- from PGCIL so as to close the long pending issues between SR & WR

constituents in total which in turn TANGEDCO will settle to Chattisgarh also.

Payable amount by PGCIL (WRTS / SRTS) to SR Constituents (as on 23.10.2017)

State/UT Total

Amount

to be

received

in Rs

Received

as on

01.12.2014

in Rs

Paid by

SRTS II

on

01.04.2016

in Rs

Paid by

SRTS II

on

01.03.2017

in Rs

Balance to

be

received

in Rs

Andhra Pradesh

& Telangana 47,05,447 3,69,848 10,16,847 3,48,203 29,70,549

Karnataka 49,79,733 3,91,407 10,76,120 3,68,500 31,43,706

Kerala 27,58,402 2,16,811 5,96,091 2,04,122 17,41,378

Tamil Nadu 47,21,994 3,71,149 10,20,423 3,49,428 29,80,994

Puducherry 9,24,035 72,629 1,99,684 68,379 5,83,343

Total 1,80,89,611 14,21,844 39,09,165 13,38,632 1,14,19,970

In the 36th

CCM, PGCIL had informed that Maharashtra is likely to release the

amount to PGCIL (apprx. Rs. 63 lakh) and would be in a position to reimburse the

amount by 15.12.2017.

SR constituents had been requested to take up pending payment issue with

concerned WR utility directly, with a copy to SRPC / WRPC Secretariat.


TANTRANCO vide letter dated 28.12.2017 (Annexure-LXXVI) had requested PCKL

to clear the dues of Rs. 26,49,88,513/- as per the decision taken in 123rd

SREB

Meeting. In the 36th

CCM held on 24.11.2017, KPTCL/PCKL had informed that

needful would be done at the earliest.

KPTCL informed that PCKL would furnish update in the SRPC Meeting.

36.2 SRPC requested the concerned entities to take necessary action to close the issues.

36.3 MD, PCKL assured that the payment issues with TANTRANSCO would be resolved

before the next SRPC Meeting.

37 AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM

37.1 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.‟

37.2 In earlier Meetings, the following had been deliberated:

TANGEDCO had informed that the Petition was scheduled for hearing before

APTEL on 22nd

August 2017. In their affidavit, they had made it clear that this

system was no more required. As per their studies, considering Jharsuguda-Angul

system in ER, 765 kV & 400 kV transmission system commissioned/under

execution/planned in SR/ER there were no constraints envisaged for evacuation of

Talcher Stage-II power in ER & SR during outage of single pole of HVDC.

37.3 Subsequently PCKL vide letter dated 07.02.2018 (Annexure-LXXVII) had invited

reference on agenda on Augmentation of Talcher Stage II Transmission system. PCKL

had requested TANGEDCO that system studies be conducted by CEA/SRLDC to

assess requirement of Talcher Stage II Augmentation System in the present scenario. It

had been requested to re-examine the requirement of Talcher Stage II Augmentation

System in the present scenario.


PCKL had stated that study by CEA or SRLDC may be required.

It was noted that during recent shutdown of HVDC pole, there was no curtailment

envisaged during single pole shutdown. In this context whether study is required or

not needs to be deliberated.

CE (NPC), CEA had stated that the Talcher augmentation was to take care of the

outage of HVDC pole and to ensure that Talcher-II power is diverted through

Gazuwaka HVDC back to back. Presently, the Gazuwaka back to back is being


utilized only upto 650 MW and strengthening from Talcher-Behrampur-Gazuwaka

may be required. This system was also to load the Gazuwaka back to back to 1,000

MW. ATC may increase by around 350 MW. CTU also endorsed these views of

CEA.

APTRANSCO, KSEBL, TANTRANSCO and TSTRANSCO had stated that the

system may not be required in the present conditions considering the upcoming

transmission elements/system. Earlier the SR was connected through HVDC only

while now it is connected through a number of 765 kV lines. Thus, usefulness has

to be examined keeping the present grid scenario. Earlier there was no option

during outage of Talcher-Kolar HVDC pole that the power be transmitted through

Gazuwaka back to back which was not the case now.

37.5 SRPC noted the above

38 GRID OPERATION

38.1 Salient Achievements

TS crossed 3,000 MW of installed capacity in Wind and Solar during November

2017 and the DSM limit was raised to 250 MW from 01.12.2017.

KKNPP Black Start Mock Drill exercise was successfully carried out on 31.10.2017

with cooperation from KKNPP, TANTRANSCO, TANGEDCO and SRLDC.

35 MW MoP allocation to Karnataka (Railways) from RGPPL was made operational

from 25.10.2017 in coordination with KPTCL, BESCOM and Railways.

KSEBL had implemented ADMS through distribution feeders ie through 11 kV

feeders. Earlier, the same was carried out through SCADA in which only 110 kV

level tripping was possible. A server would be computing the requirement and

feeders tripped automatically and the same will be displayed in the control room.

SRLDC commissioned the new Reporting and Scheduling Software.

First unit of Stage I and second unit of Stage II at Kaiga GS had completed 546 and

535 days continuous running as on 10.11.2017.

MAPS had placed on record the appreciation for the cooperation extended by

TANTRANSCO in patrolling the evacuation lines and in resolving other grid

connected issues.

MVAR Capability Test in respect of BTPS Unit I (KPCL) was carried out on

09.09.2017 with cooperation / participation from KPCL, KPTCL, SRLDC and

SRPC.

38.2 Grid Events/ Highlights during August 2017

AUFR, df/dt Joint Validation with states completed for Kerala and Puducherry. With

this, Joint Validation was completed for all the states.

PTR-2 at 220/11 kV LIS SS Machumarri in Kurnool district of 63 MVA Capacity

was commissioned on 01.08.2017 by APTRANSCO.

PTR-3 at 220/11 kV LIS SS Machumarri in Kurnool district of 63 MVA Capacity


220/132 kV SS Narasaraopet in Guntur Dist of existing 2 x 31.5 MVA was

commissioned on 04.08.2017 with augmented capacity of 3 x 31.5 MVA by

APTRANSCO.

220 kV D/C line from 400/200 kV SS Maheshwaram to Fabcity I & II of 47 Ckm

was commissioned on 20.08.2017 by TSTRANSCO.


220 kV D/C line from 400 kV SS Veltoor to 220kV Switching Station Thimmajipet I

& II of 45 Ckm was commissioned on 24.08.2017 by TSTRANSCO.

38.3 Grid Highlights during September 2017

Black Start Restoration Workshop for Karnataka Completed on 08th

September 2017

at BTPS.

Black Start Restoration Workshop for Telangana Completed on 22nd

September 2017

at KTPS.

MVAR Capability Testing of BTPS completed on 09th

September 2017

RGMO Meeting completed for TN on 25th

September 2017 and CGS on 27th

September 2017.

SR I, Power grid vide letter dated 26.09.2017 had informed that the following assets

under transmission system associated with “Eastern Region strengthening Scheme-

IX” have been put under Commercial Operation w.e.f 00:00 hrs of 27th

September

2017:

400kV, 1 x 125 MVAR, Bus Reactor at Gazuwaka (East bus) along with

associated bays and equipments.

SR I, Power Grid vide letter dated 20.10.2017 had informed that the following

transmission system associated with “Provision of line bays for the scheme –

Connectivity lines for Maheshwaram (Hyderabad) 765/400 kV Pooling Station” have

been put under Commercial Operation w.e.f 00:00 hrs of 21st October 2017:

2 Nos. of 400kV GIS line bays at Nizamabad (PG) for termination of

Nizamabad – Yeddumailaram (Shankarpalli) 400kV D/C line.

4.2 MW and 30.85 MW of Wind mills (Private) were added in AP and TN

respectively. 129.5 MW of Solar (Private) was added in TS.

Mock test on SPS of Talcher-Kolar poles were carried out on 27.09.2017.

38.4 Grid Highlights during October 2017

Black Start Restoration Workshop for Tamil Nadu Completed on 24th

October 2017

at NCTPS Stage - I.

Black Start Restoration Workshop for Andhra Pradesh Completed on 27th

October

2017 at VTPS

KKNPP Mock drill exercise conducted on 31st October 2017.

0.225 MW of Wind (Private) was added in TN. 59.996 MW and 235.896 MW of

Solar (Private) were added in AP and TS respectively.

38.5 Grid Highlights during November 2017

MVAR testing at NTPL completed on 01.12.2017

Kerala Black Start Restoration Workshop conducted on 17th

November 2017 at

Thrissur Substation, with participation of officers through VC from 9 locations.

Srisailam Left Bank pump mode operation started from 9th

November 2017.

220 kV D/C line from Palmaneru to Madanapalli in Chittoor district of 116 Ckm was

commissioned on 10.11.2017 by APTRANSCO.

220kV 2nd

circuit from Bommur to LILO point and LILO to Bavojipeta (Korukonda)

Switching Station in East Godavari District of 34 Ckm was commissioned on

17.11.2017 by APTRANSCO.

220 kV D/C line from Bavojipeta to Purushothapatnam in East Godavari district of

21 Ckm was commissioned on 17.11.2017 by APTRANSCO


220 kV D/C line from Bavojipeta to Ramavaram in East Godavari district of 29 Ckm

was commissioned on 17.11.2017 by APTRANSCO

220 kV Switching Station at Bavojipeta (Verukonda) in East Godavari Dist was

commissioned on 17.11.2017 by APTRANSCO

220/132 kV SS Kakinada in East Godavari Dist of Existing 3 x 100 MVA was

commissioned on 26.11.2017 by APTRANSCO with augmented capacity of 1 x 60 +

2 x 100 MVA.

LILO of 220 kV Regumangadda- Gudipalligattu I to 220/11 kV SS Yelluru Water

Grid Substation in Mehaboobnagar district of 7 Ckm was commissioned on

03.11.2017 by TSTRANSCO.

PTRs-2 220/11 kV SS Yelluru Water Grid Substation in Mehaboobnagar district of

capacity 50 MVA was commissioned on 03.11.2017 by TSTRANSCO.

400/220 kV Maheshwaram in existing 500 MVA was commissioned on 13.11.2017

by TSTRANSCO with augmented capacity of 500 MVA.

400/220 kV Narsapur in existing 630 MVA was commissioned on 24.11.2017 by

TSTRANSCO with augmented capacity of 315 MVA.

24 MW, 13.975 MW and 4.5 MW of Wind (Private) were added in AP, Ker and TN

respectively. 22 MW and 345.896 MW of Solar (Private) were added in AP and TS.

38.6 Grid Highlights during December 2017

75 MW power from WR ISGS to Telangana allocated from 30th

December 2017

Kudgi unit II (800 MW) Commissioned on 31st December 2017 as per NTPC.

220/132 kV SS at Madanapalli I & II in Chittoor district with 200 (MVA) capacity


220 kV SS Parawada in Visakhapatnam Dist of existing 2 x 100 MVA was

commissioned on 11.12.2017 by APTRANSCO with augmented capacity of 3 x 100

MVA.

220 kV SS Undi in West Godavari Dist of existing 3 x 100 MVA was commissioned

on 12.12.2017 by APTRANSCO with augmented capacity of 1 x 160 + 2 x 100

MVA.

LILO of 220 kV Yelluru - Gudipalligattu to 220/11kV SS Gouridevipally I in

Mehaboobnagar district of 4 Ckm was commissioned on 08.12.2017 by

TSTRANSCO.

220/11 kV Gouridevipally I SS at Mehaboobnagar district with 50 (MVA) capacity


220 kV D/C line with Multi Circuit Towers from proposed 400/132 kV SS Nirmal I

& II (Test charged) of 9 Ckm was commissioned on 29.12.2017 by TSTRANSCO.

400 kV Quad Moose /DC line from 400kV Julurupadu I&II SS TO 400 kV Suryapet

SS of 110 Ckm was commissioned on 23.12.2017 by TSTRANSCO.

400/220 kV Dindi SS in existing 1 x 315 MVA was commissioned on 20.12.2017 by

TSTRANSCO with augmented capacity of 2 x 315 MVA.

220/132/33kV SS Dichpally in existing 2 x 160 + 2 x 100 MVA was commissioned

on 07.12.2017 by TSTRANSCO with augmented capacity of 3 x 160 + 1 x 100

MVA.

220/132 SS Kamareddy in existing 2 x 100 MVA was commissioned on 16.12.2017

by TSTRANSCO with augmented capacity of 1 x 160 + 2 x 100 MVA.


26 MW of Wind (Private) were added in AP. 2.006 MW and 133 MW of Solar

(Private) were added in AP and TS.

38.7 Grid Highlights during January 2018

For the first time, Nagarjuna pump operations had started. During 09.01.2018 to

01.02.2018, NSHES / TSGENCO Units 2 to 8 were tested successfully in pump

mode operation. During this season, only 3 units can be operated simultaneously due

to some constraints in suction side of the water conducting system.

“Black Start Restoration procedure of Southern Region 2018” document was

released by SRLDC on 31.01.2018.

KPTCL met maximum demand 10,347 MW till date on 12.01.2018.

Allocation of power from the unallocated power of coal based stations of NTPC for

bundling with solar power under National Solar Mission Phase II Batch II Tranche I

to Andhra Pradesh, Telangana and Karnataka was made. As on till date Telangana is

allocated 130 MW from WR and 50 MW from ER. AP is allocated 75 MW from

WR. Karnataka is allocated 250 MW from WR.

KSPDCL vide letter dated 30.01.2018 had informed that 1 x 150 MVA, 220/66 kV

transformer substation along with 4 nos. of 66 kV bays established by KSPDCL for

evacuation of solar power generation from 2,000 MW Pavagada solar park along

with 220 kV transmission line, 66 kV terminal bays with associated equipments,

communication system from sending end to receiving end, metering, telemetering

and protection system had been put under commercial operation from 22:30 hours of

29.01.2018.

220 kV line on Multi Circuit Towers for making LILO of both circuits of existing

220 kV Budidampadu – Warangal D/C line to proposed 220/132 kV SS

Mahabubabad I,II,III&IV (5.1 km x 4 = 20.4 Ckm) of 20.40 Ckm was commissioned

on 29.01.2018 by TSTRANSCO.

220/132 kV SS PTR I Mahabubabad in Warangal district with 100 (MVA) capacity


5 MW of Wind (Private) were added in TN. 0.002 MW and 14 MW of Solar

(Private) were added in AP and TS. Bio Mass of 1.3 MW was added in AP.

38.8 Installation of Shunt Capacitors

Progress of installation of capacitors by the constituents during the year

2017-18 is furnished in the Table below:

(Figures in MVAR)

State Requirement

for 2017-18

Installed during the year

2017-18 up to Jan 2018

Andhra Pradesh 1625.2 277.4

Telangana 837.2 325.0

Karnataka 1633.7 186.6

Kerala 0 0

Tamil Nadu 100.8 19.2

Puducherry 26.4 0

38.9 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 Aug 2017

to Nov 2017:

Description

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala

Tamil

Nadu Puducherry

Southern

Region

August 2017

Highest 28.46 33.40 31.28 43.15 36.38 57.80 28.64

Date (Day) 08.08.2017

(Tuesday)

19.08.2017

(Saturday)

28.08.2017

(Monday)

21.08.2017

(Monday)

21.08.2017

(Monday)

22.08.2017

(Tuesday)

31.08.2017

(Thursday)

Lowest 11.99 16.40 14.12 28.38 13.97 20.74 4.23

Date (Day) 17.08.2017

(Thursday)

05.08.2017

(Saturday)

02.08.2017

(Wednesday)

27.08.2017

(Sunday)

27.08.2017

(Sunday)

29.08.2017

(Tuesday)

10.08.2017

(Thursday)

Average 19.29 23.70 22.79 35.70 22.61 31.46 16.45

September 2017

Highest 27.42 30.18 38.07 51.20 37.80 51.22 30.99

Date (Day) 22.09.2017

(Friday)

25.09.2017

(Monday)

18.09.2017

(Monday)

18.09.2017

(Monday)

06.03.2017

(Monday)

29.09.2017

(Wednesday)

18.09.2017

(Monday)

Lowest 14.07 12.77 17.31 27.18 12.66 16.18 12.46

Date (Day) 30.09.2017

(Saturday)

06.09.2017

(Wednesday)

03.09.2017

(Sunday)

13.09.2017

(Wednesday)

10.09.2017

(Sunday)

17.09.2017

(Sunday)

03.09.2017

(Sunday)

Average 19.63 22.07 29.81 34.76 22.79 29.95 19.40

October 2017

Highest 30.72 47.45 45.93 39.78 36.09 43.31 32.64

Date (Day) 23.10.2017

(Monday)

20.10.2017

(Friday)

03.10.2017

(Tuesday)

03.10.2017

(Tuesday)

20.10.2017

(Friday)

19.10.2017

(Thursday)

31.10.2017

(Tuesday)

Lowest 12.27 12.19 16.59 29.61 16.38 22.43 13.79

Date (Day) 19.10.2017

(Thursday)

19.10.2017

(Thursday)

29.10.2017

(Sunday)

01.10.2017

(Sunday)

27.10.2017

(Friday)

08.10.2017

(Sunday)

29.10.2017

(Sunday)

Average 19.30 22.93 33.36 34.94 23.91 31.79 21.30

November 2017

Highest 36.73 30.51 27.38 40.02 41.30 48.12 26.18

Date (Day) 29.11.2017

(Wednesday)

13.11.2017

(Monday)

13.11.2017

(Monday)

22.11.2017

(Wednesday)

06.11.2017

(Monday)

06.11.2017

(Monday)

27.11.2017

(Monday)

Lowest 17.87 18.12 14.88 25.19 17.07 25.03 14.11

Date (Day) 06.11.2017

(Monday)

26.11.2017

(Sunday)

01.11.2017

(Wednesday)

19.11.2017

(Sunday)

19.11.2017

(Sunday)

21.11.2017

(Tuesday)

26.11.2017

(Sunday)

Average 25.01 24.06 22.55 34.83 29.21 35.25 19.97

December 2017

Highest 41.21 38.19 29.33 40.50 42.26 46.52 27.90

Date (Day) 25.12.2017

(Monday)

25.12.2017

(Monday)

04.12.2017

(Monday)

18.12.2017

(Monday)

04.12.2017

(Monday)

01.12.2017

(Friday)

04.12.2017

(Monday)

Lowest 31.66 24.86 20.01 30.13 21.79 26.48 17.23

Date (Day) 01.12.2017

(Friday)

09.12.2017

(Saturday)

17.12.2017

(Sunday)

24.12.2017

(Sunday)

31.12.2017

(Sunday)

10.12.2017

(Sunday)

10.12.2017

(Sunday)

Average 36.44 31.02 24.44 36.74 30.80 36.72 22.61

January 2018

Highest 44.09 39.88 27.51 41.23 36.75 49.38 30.19

Date (Day) 23.01.2018

(Tuesday)

10.01.2018

(Wednesday)

11.01.2018

(Thursday)

03.01.2018

(Wednesday)

16.01.2018

(Tuesday)

11.01.2018

(Wednesday)

08.01.2018

(Monday)

Lowest 36.56 30.66 19.73 29.11 23.08 26.01 21.29

Date (Day) 20.01.2018

(Saturday)

01.01.2018

(Monday)

17.01.2018

(Wednesday)

14.01.2018

(Sunday)

07.01.2018

(Sunday)

07.01.2018

(Sunday)

26.01.2018

(Friday)

Average 39.61 35.48 23.74 36.52 30.32 37.06 25.76

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


38.10 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

August 2017 0.00 0.03 10.79 47.50 28.80 12.88 0.01 76.30 49.99

September 2017 0.00 0.04 14.71 52.94 24.35 7.95 0.01 77.29 49.98

October 2017 0.00 0.02 16.99 52.31 23.01 7.67 0.00 75.31 49.97

November 2017 0.00 0.08 19.72 49.96 20.89 9.33 0.02 70.85 49.97

December 2017 0.00 0.00 13.14 45.82 27.40 13.57 0.07 73.22 49.98

January 2018 0.00 0.01 11.14 50.32 27.36 11.11 0.06 77.68 49.98

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

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

frequency by some of the constituents is being regularly deliberated in the OCC

forum. Utilities were requested to kindly adhere to the Regulations in this regard.

39 REIMBURSEMENT OF SRPC EXPENDITURE

39.1 Statement showing net amount payable by Member Utilities of SRPC for the year 2017 -

18, after adjustment of surplus/deficit for the previous period is furnished in Annexure-

LXXIX.

Members were kindly requested to ensure payment, wherever due.

39.2 Enhancement of contribution to the SRPC Meeting Fund

Increase in the Annual Subscription towards SRPC Subcommittee Meetings from Rs

75,000/- per annum to Rs.1,00,000 was proposed. The last increase had earlier been

approved in the 10th

SRPC Meeting held on 02.07.2009.

TCC had recommended for this enhancement.

SRPC approved the enhancement of Annual Subscription from Rs 75,000 to Rs 1,00,000

with effect from the financial year 2018 -19.

40 STATE-WISE ALLOCATION OF 540 MW POWER FROM RGPPL TO

RAILWAYS

40.1 Ministry of Power vide Order dated 17.03.2017 had allocated 540 MW of power from

Ratnagiri Gas and Power Private Limited (RGPPL) to Indian Railways. Allocation to SR

States (out of 540 MW) was as under:


State Nodal

Railway

Maximum load in MW after availability of corridor

between NEW Grid and SR*

Telangana SCR 50

Tamil Nadu SR 100

Karnataka SR 35

35 MW MoP allocation to Railways (Karnataka) from RGPPL was operational from

25.10.2017. In the OCC Meetings, TSTRANSCO and TANTRANSCO had been

requested to kindly take steps for operationalization of the allocation.


41 REPORT OF POLLUTION MAPPING OF SR BY CPRI

41.1 M/s CPRI had prepared the draft report along with pollution map of SR after completion

of six set of measurements spread over two years carried out by PGCIL & STU of SR.

PGCIL had forwarded the draft report to various STUs seeking comments/inputs on the

draft report. CPRI had presented the highlights of draft report of Pollution Mapping of SR

in the 138th

OCCM held on 11.12.2017 (pollution map of the states and SR is enclosed at

(Annexure-LXXX). All constituents had been kindly requested to make use of the

pollution mapping.

41.2 TCC suggested that the pollution map may be appropriately considered for future design

of transmission assets.


42 OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE

42.1 POSOCO‟s report on Operational Analysis for Optimization of Hydro Resources &

facilitating Renewable Integration in India had been discussed in detail in the 32nd

SRPC/31st TCC Meetings. Chairperson, SRPC had concluded, „It was almost unanimous

that the final decision on hydro optimization should be left to the states. As suggested by

CMD, KSEBL, state-wise analysis for hydro operation could be carried out by POSOCO

in coordination and close consultation with SLDCs‟. Chairperson, SRPC vide letter dated

23.08.2017 (Annexure-LXXXI) had also taken up the concerns of SR constituents with

Ministry of Power on the above subject.

42.2 In the OCC Meetings, SRLDC had informed that NLDC had desired to conduct Meeting

with KSEBL and KPTCL respectively on the subject. States had pointed out that:

It is States/LDC prerogative to plan their LGB, including hydro optimization and

support for national peak should not be insisted upon by NLDC.

States are utilizing their own resources in the most optimal manner and the issue has

been deliberated in detail in the 31st TCC / 32

nd SRPC Meetings.

During peak hours market price may be less, while during day time market price may


be more. States may generate higher hydro during day and conserve during evening

when price is less by opting for market. If NLDC/CEA could come up with a market

mechanism, the suggestion would be appreciated since State Peak and National Peak

may be at different periods.

After deliberations, SRLDC was requested to convey these views of SR constituents to

NLDC.

42.3 In the TCC Meeting the following had been noted:

NLDC had stated that there was further scope of optimization in hydro generation and

even in pump mode operation among the states.

Director (GM), CEA had informed that as per the report, around 800 MW of hydro

support for peaking may be available from SR hydro stations. The concerned were

requested to kindly look into this aspect.

States expressed that while performance assessment was based on installed capacity

only, there were a number of other factors / considerations / directives applicable for

hydro utilization/optimization. These comments had been extensively discussed in the

31st TCC / 32

nd SRPC and also communicated to NLDC.

It was noted that a Meeting between NLDC and States would be conducted within one

month on this matter.


43 DEFAULT IN PAYMENT OF OUTSTANDING DUES BY BENEFICIARIES

43.1 PGCIL vide letter dated 09.01.2018 (refer Annexure-XXXVII) had furnished details of

outstanding dues for more than 60 days as on 04.01.2018 in respect of defaulting

beneficiaries of POWERGRID. The dues as on 12.02.2018 are as under:

Rs. in Cr.

Sl No. DIC Total dues >60 Days dues

1 TANGEDCO 160.85

2 Karnataka (BESCOM) 79.04

3 Karnataka (GESCOM) 73.77 26.66

4 Karnataka (HESCOM) 94.31 24.69

5 Karnataka (CESC) 61.71 23.89

6 Jindal 24.24

7 CEPL 37.56

8 KSK Mahanadi 21.91 8.44

9 Others 10.18

43.2 In the TCC meeting, PGCIL had requested concerned utilities to kindly liquidate the

outstanding dues on priority.

43.3 SRPC requested the concerned entities to expedite the payments.

44 INCLUSION OF DRAWAL OF MAHE IN REA

44.1 Issue of inclusion of drawal of Mahe Region of UT of Puducherry in REA was under

deliberation in the SRPC/TCC/CCM meetings. In the 32nd

SRPC Meeting, the following

had been noted:


SE-I, PED informed that they were in final stage of settlement and hopefully they

would migrate to REA by next month.

CMD, KSEBL stated that there are some dues to be cleared and subject to that matter

would be considered. However, PED should take necessary action to settle the old

payment issues at an early date.

44.2 It had been agreed in the 36th

CCM to commence the Mahe drawal accounting in REA

from 4th

December, 2017. Puducherry vide letter dated 05.12.2017 (Annexure-LXXXII)

had informed that Mahe had been included in the UT of Puducherry drawal for REA and

other commercial computations.


45 UNREQUISTIONED SURPLUS (URS)

45.1 Hon‟ble CERC in Petition No. 16/SM/2015 in matter of Difficulty encountered in

implementation of the Commission order dated 5.10.2015 in Petition No. 310/MP/2014

regarding scheduling of unscheduled Surplus Power from the Inter-State Generating

Stations vide Order dated 17.10.2017 had passed the Order :

„As an interim measure, we had issued the following directions in partial

modification of our directions in the order dated 5.10.2015, pending final decision

on the issue: “Where both the generating station and its beneficiaries (surrendering

and requesting beneficiaries) give their standing consents in writing to RLDC that

the decision of the concerned RLDC will be binding on them with regard to

scheduling and dispatch of URS power, the concerned RLDC shall schedule such

URS power to the requesting beneficiaries in relative proportion to the quantum

requested by them. In other cases, RLDCs shall schedule URS power on the basis of

the consents submitted by the generating stations in terms of the order dated

5.10.2015.”

After issue of the interim directions as above, no difficulty with regard to scheduling

of URS power has been brought to the notice of the Commission. Therefore, we are

of the view that the directions in para 32 of the order dated 5.10.2015 and the

interim direction vide Record of Proceedings dated 5.1.2016 will help in smooth

scheduling of the URS power from ISGSs.

Accordingly, where both the generating station and its beneficiaries (surrendering

and requesting beneficiaries) give their standing consents in writing to RLDC to the

effect that the decision of the concerned RLDC will be binding on them with regard

to scheduling and dispatch of URS power, the concerned RLDC shall schedule such

URS power to the requesting beneficiaries in relative proportion to the quantum

requested by them.

………

In such cases, if the generator wishes to sell the regulated power as URS power or in

the market including power exchange, the consent of beneficiary whose share of

power is regulated will not be required.

……………

Regarding other questions we have perused the Operating Procedure of SRLDC

available on SRLDC website which is extracted as under:

“9.2 ALLOCATION OF UN-REQUISITIONED SURPLUSES….The URS Re-

Allocation will be on first come first serve basis however the request received in the

same time block will be treated at par & shared on proportional basis”.

Accordingly, we direct that respective RLDCs should decide the protocol in this


regard after consultation with ISGSs and beneficiaries in the region and place the

protocol in the public domain for the information and compliance of all concerned.‟


46 RSD & TECHNICAL MINIMUM

46.1 NTPC had filed a Petition No. 130/MP/2017 in the matter of, „Petition under Section 79

of the Electricity Act, 2003 read with Part 7, Clause 4 of the CERC (IEGC) Regulations

2010 in regard to difficulties faced in implementation of the Mechanism for

compensation for degradation of Heat rate, APC and SFC due to Part Load Operation

and Multiple Start/ Stops of Units.‟ In the ROP (for date of hearing 20.07.2017) Hon‟ble

Commission had directed to issue notice to the Respondents on admissibility of the

Petition. The Petition was to be listed for hearing on 18.1.2018.

46.2 NLC had filed Petition No. 144/MP/2017 in the matter of, „Petition under CERC (IEGC)

(Fourth Amendment) Regulations 2016 and CERC's DOP on Reserve Shutdown and

Compensation Mechanism dated 5.5.2017 for seeking upward revision of the Technical

Minimum fixed for schedule of operation of NLCIL lignite based Generating Stations

(TPS I Expn, TPS II stage 1 & 2, TPS II Expn) and other related issues.‟ In the ROP (for

date of hearing 27.07.2017) Hon‟ble Commission had admitted the petition and directed

to issue notice to the Respondents on admissibility of the Petition. The Petition was to be

listed for hearing on 18.1.2018.

46.3 In the OCC Meetings, some of the constituent states had expressed concern that units

had not been taken for RSD though there was huge surrender and the demand was also

low (for ex on Deepawali day). In the 138th

OCC Meeting, SRLDC had made a

presentation of the procedure / guideline under which units can be taken under RSD.

46.4 TCC had noted the above and observed that the CERC approved RSD/TM Procedure

needs to be followed.


47 NON-ADHERENCE TO THE MAINTENANCE SCHEDULE SPECIFIC CASE OF

OVERHAULING OF TALCHER STAGE II UNITS

47.1 Issue of non-adherence of the maintenance schedule of Unit 4 of Talcher-II was discussed

in the 31st TCC meeting. NTPC had informed that major overhaul was planned at U-4 of

Talcher-II; deployment of tower crane had lot of issues since it was a running plant. Such

delay would be avoided in future and suitable care would be taken. Necessary instructions

had already been communicated to the stations to adhere to the maintenance schedule.

47.2 KSEBL vide E-mail dated 05.09.2017 had expressed concern regarding the non-adherence

of maintenance schedule of Talcher Unit III. KSEBL had expressed concern regarding the


repeated change in schedule of AMP of Talcher Unit III. Chairperson, SRPC vide letter

dated 13.09.2017 (Annexure-LXXXIII) had taken up the issue with CMD, NTPC and had

requested to kindly use his good offices to look into the matter and arrange to give strict

instructions to the concerned to strictly adhere to the finalized Maintenance Schedule. Also

it was requested that in case it was necessary to shift the schedule on account of any

reason, the same needs to be done in close consultation with states/RLDC/RPC.

47.3 Subsequently NTPC vide letter dated 11.10.2017 (Annexure-LXXXIV) had assured that

in future, NTPC would adhere to maintenance schedule as decided amongst the

constituents in the OCC Meeting.


48 URS ALLOCATION TO NON-BENEFICIARY

48.1 In the Sub-committee Meetings it had been suggested that though a few states are not

having share in some of the CGS in SR, they could be allowed to avail the URS power.

SRPC had approved that URS could also be reallocated to the non-beneficiaries in

Southern Region. Chairperson, SRPC would be kindly requested to take up this matter

with MoP.

48.2 Accordingly Chairperson, SRPC vide letter dated 29.08.2017 (Annexure-LXXXV) had

taken up the issue with MoP and requested that MoP may kindly bestow its attention on

the matter regarding URS Utilization by non-beneficiaries within a Region.


49 OUTAGE CATEGORISATION UNDER DEEMED AVAILABILITY

49.1 PGCIL had been requesting deemed availability for major R&M and upgradation works

like at Talcher & Kolar HVDC terminals (letter dated 07.12.2017 enclosed as Annexure-

LXXXVI) etc. The cost is being booked under O&M for most of these activities.

Outages are being categorized as deemed under clause 5(i) of the Procedure for

calculation of Transmission System availability Factor for a Month.


50 TECHNICAL COMMITTEE FOR IMPLEMENTATION OF FRAMEWORK ON

RENEWABLE AT STATE LEVEL -FOR

50.1 FOR vide their communication dated 02nd

May 2017 had informed that a Technical

Committee under the Chairmanship of Member, CERC had been formed at the direction of

Forum of Regulators (FOR). This Committee comprises of Technical Members of State

Commission of renewable rich States, viz. Tamil Nadu, Gujarat, Rajasthan, Maharashtra,

Andhra Pradesh, Karnataka and Madhya Pradesh. The objectives of the Committee include

facilitating implementation of Regulations for Forecasting, Scheduling and Deviation

Settlement at the State level, implementation of ABT framework and Ancillary Services in


member States, among others. The Committee in its eleventh Meeting held in Chennai on

28.03.2017 had decided that Sub-Groups be constituted in Northern Region, Western

Region and Southern Region (three RE rich regions) headed by the Member Secretaries of

the respective Regional Power Committees (RPCs) to examine this issue. This Sub-Group

shall inter-alia examine feasibility and modality of cooperation among states in the

respective region for ensuring optimum utilization of generation resources with least cost

options for balancing across the region. Subgroup Meeting of SR was conducted in SRPC,

Bengaluru on 07th

June 2017.

50.2 A Meeting of the Heads / Representatives of the Sub-Groups had been convened under the

Chairmanship of Member, CERC on 18.8.2017 in CERC, New Delhi to review the

progress on framework for regional co-operation. The Minutes of the Meeting is at

Annexure-LXXXVII. SRPC vide letter dated 14.09.2017 (Annexure-LXXXVIII) had

conveyed the feedback as concluded in the 135th

Meeting of OCC.


51 TECHNICAL COMMITTEE CONSTITUTED BY CEA

51.1 A Technical Committee had been constituted by CEA for study of optimal location of

various types of balancing energy sources/energy storage devises to facilitate grid

integration of Renewable Energy Sources and associate issues. Subsequently a Meeting of

Sub- Group of Southern Region formed under the Technical Committee was conducted on

24th

March 2017. The second Meeting of the Technical Committee was held at Chennai on

09.05.2017. The final meeting was held at New Delhi on 29.06.2017.

51.2 CEA had submitted the final report in December 2017 to MoP (report available on CEA

website http://cea.nic.in/reports/others/planning/resd/resd_comm_reports/report.pdf). The

following were the recommendations:

I. Renewable Purchase Obligation (RPO) trajectory as per the revised Tariff Policy,

notified on 28.1.2016, is uniform for all States and therefore, there is a need to share

the balancing charges/financial implication associated with balancing requirements

also on pro-rata basis. As per present norms, RPOs have been prescribed on the basis

of consumption of MUs, after deducting consumption by states from hydro power

generation. The balancing charge/financial implication should therefore also to be

shared in the same ratio.

II. There are two types of balancing generation required, the balancing for uncertainty,

i.e. deviation of actual from schedule which cannot be forecasted within the accurate

limits prescribed, and the generation capacity required to ramp up to meet the

variability due to reduction of generation from wind and solar, even if these can be

forecasted accurately and are known. Both these factors cause a financial impact on

the existing thermal generation.

III. Efficiency of thermal power plants goes down at lower loads, and if they are to

participate in balancing requirement, these need to be compensated on account of


high availability of RE generation. High RE generation also calls for backing down

of cheaper conventional sources, because of must run status of RE. Frequent start-

stop of machines and frequent ramping up and down, subjects the boiler and turbine

to greater deterioration of equipment and higher O&M needs. The thermal stresses

are highest in case of starting from cold condition and very less for ramping up and

down. There is a cost to these.

IV. Hydro and gas based power plants should preferably be used for balancing. To

facilitate gas plants for balancing, gas supply needs to be modulated as per

requirement.

V. Balancing source could be located either within the boundary of a State or outside the

boundary of the host State.

VI. There is a need to discriminate between balancing power needs on account of load

variation from that on account of variability in RE generation. Real time renewable

generation data acquisition is required by the States to see to what extent the states

deviation under Deviation Settlement Mechanism (DSM) is due to renewable

variation.

VII. Ancillary Services in India may be started to ensure capacity on a permanent basis

for grid security. Balancing sources should form part of the bigger umbrella of

Ancillary services. There is a need to categorize various type of balancing sources,

based on response time, to be activated within seconds, minutes and hours, and price

for each category determined through bidding. The balancing generation should have

a commitment charge and a usage charge for a certain pre-defined usage. If usage

exceeds the same, there should be an additional payment for the extra usage, all pre-

defined. Payment should also be based on performance.

VIII. The extent of balancing required for balancing renewables may be extracted from

these Ancillary Services.

IX. Balancing resources of the States/Centre/Private sector generators could be

surrendered and treated as common resources, and the owner of these assets

compensated if they win the bid for ancillary services. For this, they would have to

set aside the contracted quantity.

X. These Ancillary Services may be kept under the control of RLDCs. Cost of these

resources need to be shared on pro-rata basis by all the beneficiaries.

XI. Demand Response is a very quick and cheap way of substituting for frequency based

ancillary services to some extent, to enable optimum utilization of generation and

transmission assets and must be implemented by all States.

XII. Limits of net DSM for load variation may be maintained as before, after segregating

it from renewable variation, with ancillary services for renewable generation

variation and frequency control under the control of the RLDCs, for managing the

grid. Alternately, the renewable rich States may manage the same within their

boundary and get paid for the financial implication by non-renewable rich States on

pro-rata basis, based on consumption, depending on calculation of the financial

implication per unit of renewable generation done on a normative seasonal basis or

weekly basis, as is done for DSM charges.

XIII. In case of the latter option, settlement of balancing charges/financial implication for

the uncertainty portion should be done post facto, on the lines of DSM charges.


XIV. Firm base load power could be supplied to neighboring hydro rich countries in return

for balancing power from them, through banking, in order to have a win-win

situation for both India and the neighboring countries.

XV. Till the time intra-state DSM Regulation by the SERCs is not operational, the

mechanism of inter-state DSM should be followed.

XVI. Cost benefit aspects need to be studied, as regard to location of new balancing

sources, versus augmentation of transmission system. This aspect assumes a higher

importance, in view of the increasing land cost in urban areas. In some cases,

location of balancing sources in the form of storage elements, near the point of

generation may be more economical.

XVII. A pilot battery project in Tamil Nadu has been proposed as a test case for a pilot

project.


52 COMMITTEE FOR PROPOSING METHODS FOR INTEGRATED OPERATIONS

OF RESOURCES IN A RIVER IN THE COUNTRY

52.1 In the 4th

meeting of the Technical Committee (held on 13.06.2017) chaired by Member

(Planning), CEA, it had been decided that in order to tackle intermittency / variability of

renewable energy generation, support of hydro power generation resources would be

required for optimum utilization of the resources. Accordingly, a Standing Committee was

constituted under the Chairmanship of Member Secretary, NRPC along with representation

from number of Central/State and concerned entities vide order dated 03.11.2017

(Annexure-LXXXIX). The TOR of the Committee is as follows:

1) Calculate hydro power potential of each individual hydro station and its month-

wise distribution over the year.

2) “Integrated Reservoir Operation of hydro power plant reservoir in a river for the

country”

3) Guidelines for fixing the reservoir levels for valley project with a view to optimum

utilization for peaking and balancing

4) Calculate peak power availability considering irrigation needs and whether the two

can be matched

5) Guidelines for operation and utilization of pump storage scheme for integration of

RE generation especially in view of shared projects.

6) Guidelines for reduction in APC of hydro station

7) Silt forecasting for hydro power plants

8) Guidelines for incentive to pump storage scheme


53 INCLUSION OF DRAWAL OF KARAIKAL REGION OF UT OF PUDUCHERRY

IN REA

Secretary, Government of Puducherry vide letter dated 5.02.2018 (Annexure-XC) has

proposed that Power Drawal of Karaikal Region of UT of Puducherry may also be

included in the Regional Energy Accounting of SRPC


TCC deliberations

TANTRANSCO had suggested that this issue could be discussed in Commercial sub-

committee.

PED had informed that the earlier inclusion of drawal of Karaikal region of UT of

Puducherry was discussed in the 23rd

SRPC /22nd

TCC Meeting held on

26/25.10.2013 when Karaikal region was not having ISTS connectivity (fully

embedded in Tamil Nadu). In that SRPC meeting, the following had been noted,

„Chairman, TANTRANSCO stated that Puducherry & Karaikal being enclave

territories in TN, the limited suggestion was that drawal of power by Puducherry at

Karaikal be under Regional Energy Accounting framework and within its regional

entitlement, provided TN transmission network permitted the same.‟ Karaikal Region

would now be connected to ISTS and drawal of power would be within REA

framework and regional entitlement of PED.

It was noted that this issue would be further deliberated in the SRPC Meeting.

SRPC deliberations

It was noted that Karaikal would be drawing power through LILO of NLY-Bahoor

line at Karaikal, which is a PGCIL ISTS line. This scheme had been approved in

Standing Committee as well as in SRPC Meetings. Electricity Department,

Puducherry had also assured that drawal (including that of Karaikal) would be

within the entitlement of its CGS drawal. There was thus no need to deliberate on

this issue in the Commercial Committee.

SRPC noted that above was in line with prevailing Regulations and due approvals

had been availed.

Finer issues relating to Metering, SCADA could be finalized in the Sub Committee

Meetings.

54 HIGH DECLARATION OF DC FROM NTPC KUDGI THERMAL POWER PLANT

FROM 01.01.2018 ONWARDS

54.1 KPTCL vide letter dated 12.02.2018 (Annexure-XCI) had brought to attention about the

high declaration of DC from NTPC, Kudgi from 01.01.2108 onwards. It had been stated

that there is a total mismatch with projected LGBR figure furnished by NTPC with respect

to Kudgi Thermal Plant to SRPC particularly from the last week of December 2017 which

had resulted in uncalled purchases made by KPTCL for meeting the demand and energy

requirement during summer and examination period based on the LGBR data. It was stated

that after COD of 2nd

unit of Kudgi, the declaration is in the range of 1,520 MW which

works out to around 36 MU/day translating to 1,080 MU instead of 471 MU furnished by

NTPC in the LGBR. In the 140th

OCCM, NTPC representative did not agree to revise DC

as per LGBR. It had been requested that this matter may be taken up and resolved in the

TCC/SRPC Meetings.

54.2 SRPC vide letter dated 06.02.2018 (Annexure-XCII) had already taken up this issue with

NTPC. Chairperson, SRPC vide letter dated 06.02.2018 (Annexure-XCIII) had


communicated the concern of beneficiaries to Chairperson, CERC. In case of new CGS

stations with higher variable charges, there would thus virtually be no need felt by the

station to maintain coal stock position as per stipulated norms to address energy security

concern. In respect of generating station whose tariff is determined by Hon‟ble CERC

there needs to be adequate Regulatory provision so that Thermal stations maintain

adequate coal stock as per norms as a requisite to declaration of full DC. This would help

avoid situation when station tends to give high DC declaration while not maintaining

adequate coal stock since due to merit order consideration it may not get scheduled fully. It

was also requested that the Hon‟ble Commission may kindly bestow its kind attention on

this matter of full DC declaration with no adequate coal stock as per norms.


KPTCL had expressed serious concern on DC variation compared to LGB projection

in case of Kudgi after the COD of Unit II from 31.12.2017. On the day of higher DC

the SLDC Control Room had contacted Kudgi Control Room and conveyed its

apprehension. Since Karnataka share was around 53 %, this was having a major impact

on availability. Based on 168/169/170 LGBR, purchases had been planned and entered

into. Besides huge backing down (of purchases, state generation, ISGS including

Kudgi), hydro was also to be availed and this was leading to heavy under-drawals.

KPTCL requested NTPC to restrict the DC to LGB figures up to March 2018 in this

scenario. Full assistance had been rendered to NTPC for Unit 2 COD declaration and

NTPC should reciprocate by restricting DC to LGB. Also, SLDC was giving minimum

schedule which was being jacked up to Technical Minimum by SRLDC leading to

undesirable increase in availability /under-drawals. The fixed charge liability was also

substantial in this regard.

It was noted that LGB is a statutory document as per provisions of IEGC and is being

used extensively for power purchase, operational planning etc. Power purchase needs

to be optimized (quantum/economics) as no state was having load shedding/power

cuts; any radical change disturbs the planning process.

NTPC had stated that the DC declaration was prerogative of Generator as per

Regulations. As per IEGC, the LGB was to be reviewed on monthly basis. Since the

installed capacity of unit is 800 MW, any change is reflected to that extent. In future,

the LGB figures would be reviewed on a monthly basis. LGB is prepared on a

yearly/quarterly basis with provision of monthly revision while DC is given on day

ahead basis and both should not be correlated. All beneficiaries were fully aware and

consulted/coordinated/informed at each step and due process had been followed for

COD of Unit II.

KPTCL had observed that without adequate coal stock, persisting coal supply issues

and unstable DC from Kudgi it was not feasible to plan the energy balance of control

area considering the likely availability from both the units and therefore LGB figures

had been considered. COD declaration did not imply that full DC had to be declared.

KSEBL, TSTRANSCO and TANTRANSCO had stated that power purchase planning

was by means of considering LGB projections. TANTRANSCO had stated that they

face similar situation during KKNPP deviations from schedule outages and hence

generation actuals should be close to their availability. KSEBL stated that adequate


coal stock was to be maintained to declare consistent DC.

CEA had stated that LGB was being used for a number of important activities and was

a document under regulatory provisions. In IEGC, LGBR falls under Outage Planning

and the monthly review is restricted to Outage coordination/rescheduling. Purchase

planning is regularly stressed considering the LGBR as the base document.

APTRANSCO had stated that all the constituents/generators vary w.r.t. LGBR based

on a number of conditions. Therefore, this issue could be settled bilaterally between

NTPC and KPTCL.

It was noted that RSD procedure needs to be followed considering the states view.

Also, the decision to go for RSD was with the generator and bringing the schedule to

Technical Minimum as a practice may not meet the objective of TM/RSD Procedure.

Bringing unit to Technical Minimum should not be at operational/economic expense of

the Control Area.

SRLDC had stated that TM/RSD procedure had been explained in the OCC forum and

if all the beneficiaries agree they would go for RSD. 55% Technical Minimum is being

followed since the provisions of Regulations were made effective.

TANGEDCO had raised certain issues on methodology for arriving at variable cost of

different stations for using it in MOD. The difference for state and central generator

was significant since different procedure/components (landed cost, royalty etc) were

being considered to arrive at the variable cost. All components to arrive at variable cost

needed to be furnished both by state & central generators so as to work out variable

cost at same platform. It was leading to distorted MOD. MOD concept is only stated in

SERC Regulation and not in CERC Regulations. TANGEDCO was suggested to

kindly take up this issue in appropriate forum.

TCC had suggested that the Kudgi DC vs LGB issue could be further deliberated in the

SRPC Meeting.

SRPC deliberations

KPTCL stated that they had gone for purchase of 900 MW keeping in view the LGB

projection of Kudgi in 170th

LGBR, wherein only 8.3 MU/day was projected (for

Karnataka) while the present share, as per DC, was more than double. Even if Kudgi

generation is backed down, the fixed charge (FC) liability for the additional DC

remains with Karnataka. It was suggested that NTPC Kudgi should restrict their DC as

per LGB projections.

Chairperson, SRPC observed that this was a critical issue which needs to be

fundamentally addressed. He therefore suggested that the issue could be deliberated in

detail in a separate Meeting.

55 ROSTER FOR HOSTING THE SRPC MEETINGS

The updated roster considering the new Members also is given below:

Sl.

No.

Constituent

/Entity

Sl.

No.

Constituent /Entity

1 UPCL 10 NTPC

2 JSWEL 11 NTPL

3 NPCIL 12 ANDHRA PRADESH


4 SGPL 13 TRADER

5 HNPCL 14 CEPL

6 TAMIL NADU 15 KARNATAKA

7 IL&FS 16 NTECL

8 PGCIL 17 KERALA

9 TELANGANA 18 NLC

56 VOTE OF THANKS

Chairperson, SRPC thanked all Members for making this SRPC Meeting successful. A

number of issues had been resolved while few issues could be reviewed in the next SRPC

Meeting. He again thanked the NLCIL Management for the excellent arrangements made

for conduct of the Meeting.

57 DATE & VENUE OF THE NEXT MEETING OF SRPC

UPCL kindly consented to host the next SRPC Meeting.

*********

Documents

SOUTHERN REGIONAL POWER COMMITTEE of the 33rd Meeting of SRPC held on 17.02.2018 Page 1 Contents 1. INTRODUCTION