Contents 1. INTRODUCTION 3 2. rdCONFIRMATION OF ...Pavagada, a 2,000 MW Solar Power Park is being developed by KSPDCL and SR-II is responsible for evacuation of this power. As a Green

Minutes of the 34th Meeting of SRPC held on 11.08.2018 Page 1

Contents

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

2. CONFIRMATION OF THE MINUTES OF THE 33rd MEETING OF SRPC ...............................................................7

3. SUPPORT OF RE GENERATORS FOR REACTIVE COMPENSATION ....................................................................7

4. RAMP RATES ................................................................................................................................................. 11

5. PROCUREMENT OF POC SOFTWARE FOR DISCOMS .................................................................................... 13

6. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE ...................................................... 13

7. MONITORING OF SCHEMES FUNDED FROM PSDF ....................................................................................... 14

8 TRANSMISSION CHARGES / SHARING RELATED ISSUES ............................................................................... 16

9 OPTIMUM HARNESSING OF RE IN SOUTHERN REGION ............................................................................... 21

10 ISSUES WITH OA CONSUMERS ..................................................................................................................... 23

11 PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER ENVIRONMENT

(PROTECTION) AMENDMENT RULES, 2015 .................................................................................................. 25

12 COAL ISSUES ................................................................................................................................................. 27

13 STATUS OF DC/GENERATION IN ISGS ........................................................................................................... 37

14 ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY .................................................................... 38

15 TTC/ATC ........................................................................................................................................................ 41

16 ISSUE OF PREVAILING OVER VOLTAGES IN SR GRID .................................................................................... 42

17 ISSUES IN RESPECT OF NPCIL ........................................................................................................................ 44

18 UPCOMING TRANSMISSION SYSTEM ........................................................................................................... 51

19 SCHEDULING OF MACHKUND AND TB DAM ................................................................................................ 67

20 NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ................................................................ 67

21 NEW PROJECTS OF STATE SECTOR & IPP ..................................................................................................... 71

22 REVIEW OF ULDC / SCADA/COMMUNICATION ............................................................................................ 72

23 URTDSM (PMU) PROJECT IN SOUTHERN REGION ........................................................................................ 75

24 EMERGENCY RESTORATION SYSTEM (ERS) .................................................................................................. 75

25 ADOPTION OF UNIFORM PROCEDURE TO PREPARE MERIT ORDER DESPATCH LIST ................................... 76

26 PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR ............................................................. 76

27 NON-AVAILING OF OCC APPROVED SHUTDOWN ........................................................................................ 82

28 COMPLIANCE STATUS OF PHASE-I AND PHASE-II OF PROTECTION AUDIT RECOMMENDATIONS .............. 84

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

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

30 COMPLIANCE STATUS OF NEW PROTECTION AUDIT RECOMMENDATIONS ............................................... 87

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

SOUTHERN REGION ...................................................................................................................................... 88

32 COMPLIANCE STATUS OF PCSC RECOMMENDATIONS ................................................................................ 89

33 COMMERCIAL COMMITTEE ISSUES .............................................................................................................. 90

34 IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION.............................................................................. 96

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

AND OTHER PROVISIONS OF CEA/CERC REGULATIONS ............................................................................. 107

36 GRID OPERATION ....................................................................................................................................... 108

37 CERTIFICATION OF NON-ISTS LINE CARRYING INTER-STATE POWER FOR THE YEAR 2018-19 .................. 115

38 EFFECT ON POC CHARGES ON ACCOUNT OF SCHEDULING WIND AND SOLAR STATIONS BY RLDC .......... 116

39 MEMBERSHIP OF TRADER IN SRPC FOR THE YEAR 2018-19 ...................................................................... 116

40 REIMBURSEMENT OF SRPC EXPENDITURE ................................................................................................. 116


41 OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE ................................................................. 116

42 RSD & TECHNICAL MINIMUM .................................................................................................................... 116

43 FREQUENT REVISION OF OUAGE PLAN BY ISG STATIONS .......................................................................... 117

44 COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF RENEWABLE ENERGY SOURCES ..... 117

45 SCHEDULING OF ANANTHAPURAMU ULTRA MEGA SOLAR PARK / RAMAGUNDAM SOLAR PROJECT ..... 119

46 KARAIKAL DRAWAL .................................................................................................................................... 120

47 GRID STUDY COMMITTEE (GSC) MEETINGS ON PACKAGE-A & PACKAGE-B .............................................. 120

48 OVR Grading of 400 kV and 765 kV Transmission Lines of Southern Region ............................................. 122

49 COMPLIANCE OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE TRANSMISSION OF

ELECTRICITY), REGULATIONS 2017 ............................................................................................................. 122

50 SPECIAL MEETING ON THE TRIPPINGS OF POLES - 1 & 2 AT HVDC GAJUWAKA SS OF POWERGRID

(SRTS-I) ....................................................................................................................................................... 122

51 SPECIAL MEETING ON THE PENDING PROTECTION ISSUES OF PUDUCHERRY SUBSTATIONS ................... 123

52 UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH TRANSMISSION NETWORK ........... 123

53 PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS ..................................................... 124

54 ROSTER FOR HOSTING THE SRPC MEETINGS ............................................................................................. 124

55 CONLCUSION .............................................................................................................................................. 125

56 DATE & VENUE OF THE NEXT MEETING OF SRPC....................................................................................... 125


SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

MINUTES OF THE 34th

MEETING OF SRPC HELD ON 11

th AUGUST 2018 AT

COIMBATORE

1. INTRODUCTION

1.1 The 34th

Meeting of Southern Regional Power Committee was conducted on 11th

August

2018 at Coimbatore. The list of participants is enclosed at (Annexure-I).

1.2 On behalf of POWERGRID, Ms Seema Gupta, Director (O&P) extended a very warm

welcome to all Members to the SRPC meeting. She especially welcomed Shri K

Vijayanand, Chairperson SRPC & CMD, APTRANSCO, Shri P S Mhaske, Member

(GO&D), CEA and all other CMDs of various utilities present here. She stated it was a

proud moment for PGCIL to organize this SRPC Meeting. Being the first SRPC Meeting

after her assuming charge as Director, it becomes all the more special to her. PGCIL team

has taken all efforts for the smooth conduct of the Meeting.

Director (O&P) stated that POWERGRID requires no particular introduction since it is

keeping the flag of India high as far as technological advances are concerned, be it a 800 kV

HVDC or 765 kV lines (which are one of the highest in the world). India can boast about

one of the largest synchronous grid with all the five regions in the country connected. One

of the proud moments was when in December 2013, SR grid was connected synchronously

with the rest of the grid. Though SR was earlier connected through HVDC links, with 765

KV Raichur- Sholapur link, it got connected to NEW grid synchronously. She stated that

during the last SRPC Meeting that she attended, Raigarh-Pugalur HVDC link had been

conceived. At that time SR was facing acute shortage of power, market used to get split and

price of electricity in SR was more compared to price in other regions. Though situation had

improved with Raichur-Sholapur, but more was required to be done and in this context

Raigarh-Pugalur HVDC link was formulated. With the active support of all SR constituents

it is going to be commissioned. SRPC is on the forefront in adopting new technologies. One

example is that the first STATCOM in India had been commissioned in SR. All Members of

SRPC need to be congratulated on being progressive and visionary as to the needs of SR. As

far as POWERGRID is concerned, there is lot of feeling and importance for Southern

Region. In SR around 50 Sub stations were being operated by POWERGRID, out of which

around 10 high capacity substations had been commissioned in the last one year. The

available power transfer inter regional capacity which was around 3,450 MW in 2013 had

increased to 9,500 MW after commissioning of Raichur-Sholapur, Angul-Srikakulam,

Wardha-Nizamabad-Hyderabad and other links. For Wardha –Hyderabad, the Planning

team as well as SR team had taken lot of efforts to commission it ahead of schedule. This

enabled lower price power being available to SR constituents. Strengthening of transmission

had led to overall reduction of power prices in the country. This forum should continue to

approve schemes which are progressive and visionary. Transmission cost in the entire value


chain of production to consumption is quite minimal. The type of benefits that adequate

transmission can accrue to the system is immense. This has been witnessed in Southern

Region with saving in cost of power purchase. This was the main reason that 6,000 MW

HVDC link from Raigarh to Pugalur & 2000 MW link to Trichur were approved. Lot of

generation is available in Raigarh and thus SR constituents are certainly going to benefit.

VSC technology from Pugalur to Trichur is first of its kind in India and proudly it is in

Southern Region. There were certain ROW issues but full support is being extended by

constituent states, CEA & MoP. This is helping enable POWEGRID to complete those lines

in an effective and timely manner. There was a period when number of lines were stuck in

SR but now the situation had improved and she extended heartfelt thanks to SR constituents,

CEA & MoP for extending timely help. It had been informed that discussions in the TCC

Meeting had been fruitful and hoped that all the points would get concluded today. She

wished all the best for this 34th

SRPC Meeting, and hoped that SR would continue to come

out with new ideas to meet the challenges ahead.

1.3 PGCIL presented a shot film in which the following was highlighted:

POWERGRID a Central Navrathna PSU is one of the world‟s largest Electric Power

Transmission Company. It has been rated „Excellent‟ under MoP since 1993-94.

It has grown from 22,228 ckm (1989) to 1,45,650 ckm of transmission lines. From

35 substations to 230 substations and transformation capacity from 12,201 MVA to

3,24,244 MVA.

POWERGRID has established global presence in constructing and operating State of

the Art power transmission network in several countries.

GoI has an objective of One Nation- One Grid-One Price and POWERGRID is the

prime mover in this regard.

In April 2001, SR-I & SR-II were bifurcated for efficient operation and

management.

SR-II was established with responsibility of transmission system in TN, Karnataka,

Kerala and Puducherry.

SR-II had increased from 3,017 ckm to 32,000 ckm, 8 substations to 34 substations

and 2,890 MVA to 25,785 MVA.

SR-II had been adjudged best performing region in POWERGRID for past several

years.

SR-II is a pioneer in Hot Line maintenance techniques avoiding outage with

improved system availability. A State of the Art Unified Load Dispatch and

Communication System ensures hassle free operation of the grid.

Kalvindapattu substation is the first completely unmanned remotely operated

substation in POWERGRID. Presently, all substations in SR-II are remotely

operated.

NTAMC had been established at Manesar for remote operation and monitoring by

experts on 24x7 basis. Back up RTAMC is located at SR-II, RHQ in Bengaluru

monitors 31 substations by deploying State of the Art monitoring, visualising and

diagnostic tools. It consists of three distinct areas SCADA, RASP & VMS.

Journey to reach the objective had been overwhelmingly satisfying. As per the

MOU, 98.5 % was the target availability assigned but subsequently it has


outperformed with transmission availability of more than 99.9 % with no grid

disturbance in SR-II since 2001.

Before 2000 there were repeated blackouts in SR but establishing HVDC Talcher-

Kolar in 2003 had brought out immense stability in SR.

Kolar HVDC has achieved 100 % availability for two years at a stretch which is a

world record.

Employ Development Centre (EDC) at Hosur is established to enhance and update

employees at par with current trends in profession.

Research & development is also carried out at Research Testing and Development

Centre (RTDC) for insulating oil testing and field test.

Pavagada, a 2,000 MW Solar Power Park is being developed by KSPDCL and SR-II

is responsible for evacuation of this power.

As a Green Corridor service TN is expected to add 7,300 MW of renewable

generation through wind mills. For this SR-II had established 400/230 kV Tuticorin

GIS.

SR-II has taken pioneering steps in bringing Smart Grid technology to all facets of

power supply value chain with development of Smart Grid Pilot Project at

Puducherry through open collaboration covering all attributes of Smart Grid in

distribution system. Battery Storage System with latest technologies is installed and

already under operation.

Upcoming power transmission of HVDC link from Raigarh in Chhattisgarh to

Pugalur in Tamil Nadu in SR-II has a capacity of 6,000 MW. HVDC link from

Pugalur in Tamil Nadu to Trichur in Kerala has a capacity of 2,000 MW further

enhancing the success story of Kolar.

Business Development Department (BDD) has been successful in providing services

for State Government clients by providing inputs through consultancy works.

PowerTel network under SRTCC has crossed 10,000 kM and poised to grow further

with commencement of new projects. It has presence in thirty major cities across the

Region.

Turnover had grown from Rs. 136.7 Crores to Rs. 2047.37 Crores while profit had

grown from Rs. 72.36 (2001-)Crores to Rs. 741.41 (2017-18).

HRD, SR-II is also highly active motivating the manpower. SR-II HQ building has

been accredited 4 stars rating under GRIHA.

1.4 Shri S R Bhat, Member Secretary, SRPC extended a hearty welcome to all esteemed

Members to the 34th

Meeting of SRPC. He extended special welcome to Chairperson

SRPC & CMD, APTRANSCO & also Member (GO&D), CEA. He thanked Director,

PGCIL, ED, SR-II and the entire team for making wonderful arrangements for conduct of

the Meeting.

1.5 Shri K Vijayanand, Chairperson SRPC & CMD, APTRANSCO welcomed Shri P S

Mhaske ,Member ( GO&D) , CEA, , Director, PGCIL, MS, SRPC , MDs, Directors and

senior officers from different utilities of Southern States, SCCL, MCL, Railways,

PGCIL, NPCIL to the 34th

Meeting of SRPC. He stated that SRPC forum, over a period

of time, has immensely helped all constituent states to sort various regional issues and


created a framework to develop the power sector within the region. In the PGCIL

presentation, different works carried out by SR-I & SR-II had been highlighted. In

similar manner each and every state had grown in leaps and bound in providing quality

power to consumers of the respective states. Other organizations such as Railways, Coal

Companies, ISGS and IPPs had also helped SR in growth. It has been informed that

majority of the issues in the TCC had been discussed; deliberated and broad

understanding had been achieved. Therefore, the SRPC Agenda could now be completed

in a meaningful manner. He thanked PGCIL for making excellent arrangement for

conduct of the Meeting.

1.6 SRPC welcomed the following new Members:

Shri P S Mhaske, Member (GO & D), CEA

Shri Y Adam, Director (Grid & Tr. Mgmt), APTRANSCO, Vijayawada

Shri H Y Dora, CMD, APEPDCL, Visakhapatnam

Dr S Selvakumar, MD, KPTCL, Bengaluru

Shri K V Shivakumar, Director (Transmission), KPTCL, Bengaluru

Shri K V C Ramanajaneyalu, Chief Engineer (E), SLDC, KPTCL, Bengaluru

Shri V Bharatheesha Rao, MD I/c, PCKL, Bengaluru

Shri Vikram Kapur, Chairman, TNEB, Chennai

Shri T Senthilvelan, Director (Transmission Projects), TANTRANSCO, Chennai

Shri G Raghuma Reddy, CMD, TSSPDCL, Hyderabad

Shri Tarsem Kumar, Secretary (Power), Govt. of Puducherry, Puducherry

Ms Seema Gupta, Director (Operations), PGCIL, Gurgaon

Shri P K Agarwal, Director (Market Operation), POSOCO, New Delhi

Shri Shaji John, CEO, NTPL, Tuticorin

Shri Kulbhushan Mittal, MD, Mittal Processors Pvt Ltd., New Delhi

SRPC also welcomed Shri D S Choudhary, Station Director, KKNPP who would be taking

over shortly as Director (O), NPCIL

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

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

Shri Jawaid Akhtar, MD, KPTCL, Bengaluru

Shri H Nagesh, Director (Transmission), KPTCL, Bengaluru

Shri R V Dilip Kumar, Chief Engineer (E), SLDC, KPTCL, Bengaluru

Shri T H M Kumar, MD, PCKL, Bengaluru


Dr M Saikumar, Chairman, TNEB, Chennai

Shri M M Nayak, CMD, APSPDCL, Tirupati

Shri A Gopal Rao, CMD, TSNPDCL, Warangal

Shri Prashant Kumar Panda, Secretary (Power), Govt. of Puducherry, Puducherry

Shri K V S Baba, CMD, POSOCO, New Delhi

Shri M Prabhagar, CEO, NTPL, Tuticorin

SRPC welcomed the following Special Invitees to this Meeting:

Shri H S Bajwa, Executive Director (Coal), Railway Board

Shri Rajesh Mishra, HOD (M&S), MCL

Shri B Krishna Rao, ED, SCCL

Dr K. Balraman, Director General, NIWE

Dr K Kasthurirangaian Chairman, IWPA

Since there were a number of issues in respect of coal supply & coal transport, MCL, SCCL

& Railways had been invited by Chairperson, SRPC to attend the Meeting as Special Invitee.

1.7 The Agenda was taken up for deliberations.

2. CONFIRMATION OF THE MINUTES OF THE 33rd

MEETING OF SRPC

2.1 Minutes of the 33rd

SRPC Meeting held on 17th

February 2018 at Puducherry had been

circulated vide letter dated 13th

April 2018.

2.2 Minutes of the Meeting were confirmed.

3. SUPPORT OF RE GENERATORS FOR REACTIVE COMPENSATION

3.1 In earlier Meetings, the following had been noted:

Solar / Wind generators have controllable reactive injection / absorption capability,

which are not getting utilized fully 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.

In the 32nd

Meeting, TCC had opined that details could be shared by the states and the

matter could be examined to arrive at some commonality in SR.

Subsequently, the following was noted:

In the Meeting held at NIWE on 28th

April 2018, NIWE had explained that support from

RE generators for MVAR interchange was very much possible.

SRPC vide letter dated 24th

May 2018 (Annexure-II) had circulated a Note regarding

MVAR power restrictions/support from RE generators. It was felt that suitable penal

rates/incentives may need to be in place for RE generators for their contribution, in the

interest of smooth grid operation.

It was noted that reactive support was required from grid operation / reliability

perspective and the same needed to be internally discussed by the SLDC / TRANSCO /

DISCOMs / Commercial sections and then it could be taken up with the RE generators.


All states had been requested to give their comments in this regard so as to help in to

arrive at consensus on this matter in Southern Region and to take the matter further.

KSEBL had informed that RE generators are not being penalized (charges suspended) on

injection or absorption of MVAR in case the same is as per SLDC instruction.

In the Special Meeting held on 09.07.2018 to discuss pending issues in respect of

Karnataka, KPTCL had informed that a Sub Committee has been agreed to be constituted

in KEGC Review meeting held on 04.07.2018 to review these aspects.

3.2 SRPC vide letter dated 24.05.2018 (Annexure-III) had taken up the issue of reactive power

support by the generating stations including RE with Hon‟ble CERC.

3.3 It may kindly be noted, that 400 kV lines connected to 400 kV Uravakonda S/S are tripping

frequently on account of persisting high voltage. Voltages at 400 kV Uravakonda S/S and

400 kV Jammalmadugu S/S were persistently very high. There were two instances of

complete outage of 400 kV Uravakonda S/S and 400 kV Jammalmadugu S/S during the

month of June 2018. This matter had also been discussed in the 75th

Meeting of Protection

Sub Committee on 28th

June 2018. It had been proposed to constitute a Group of Officers

from SRLDC, SRPC and the States who would visit major RE nodes facing high voltage

and suggest any improvement in the Operating Procedure.

3.4 The following had been deliberated in the TCC Meeting:

Contribution of RE generation towards active and reactive power support cannot be

overlooked especially since they are contributing significantly towards the demand met.

In Karnataka for instance, about 80% of the demand was met through RE sources at one

instant of time.

Billing mechanism, PPA provisions, ERC Orders etc with regard to RE reactive energy

needs to align with system grid operation requirements. Since Charges were for drawal of

reactive energy, reactive energy was always being injected into the grid irrespective of

the voltage level. Details of reactive power billing adopted in SR states for Wind and

Solar is furnished as Annexure-IV.

Circular dated 17.07.2017 of KPTCL classifying valid and invalid VAR was in line with

grid operation requirements. SRPC Secretariat vide letter dated 03.08.2018 (Annexure-

V) had taken up certain issues in this regard with KPTCL.

To verify the technical capability of RE generators, MVAR capability testing had been

carried out at Urvakonda (Wind Pooling Station) in AP on 25th

and 26th

July 2018 and at

Pavagada (Solar Pooling Station) in Karnataka on 2nd

and 3rd

August 2018. Minutes of

the meeting dated 25.07.2018 on high voltage issues at Urvakonda and Jammalmadugu

(Meeting held on 23.07.2018) are available at SRPC website. Valuable support extended

by APTRANSCO, KPTCL and also the efforts of SRLDC and SRPC Secretariat were

placed on record. KSPDCL, M/s Suzlon (Urvakonda) and M/s Adani (Pavagada) had

actively participated in the exercise which was also appreciated by the forum. Reactive

charges had been suspended on these days to faithfully measure and verify technical

capability of the turbines / inverters. Similar exercise had also been planned at Kamuthi

(Solar) for which M/s Adani and TANTRANSCO had kindly agreed.


At Urvakonda there was MVAR absorption upto 400 MVAR and the voltage had touched

around 400 kV. This was an achievement because since its commissioning, the sub-

station had never recorded voltage of 400 kV. Around 8 kV voltage improvement was

attained. Technically, it had been demonstrated that reactive support was possible from

WTGs, provided commercial conditions are made favorable. Two reports had been made

by SRPC Secretariat and SRLDC which had been circulated. Urvakonda had faced two

grid disturbances in the recent past which had led to loss of generation. It was noted that

lines were getting tripped or being tripped on account of high voltage. Certain changes in

over voltage settings had been suggested for implementation in that area. Capability of

WTGs could be used to control the voltages during wind season and thus more lines can

be kept in service improving the reliability. Thus generation reliability would enhance,

during off season when reactive support would be limited , operator may be required to

take out few lines to control over voltages.

At Pavagada it was noted that each 50 MW SPD could support with 15 MVAR (though

the technical capability is more) absorption at night. During day time, 250 MVAR had

been tested against normal absorption level of around 50 MVAR (at 400 kV).

The way forward suggested is as follows:

Policy intervention for appropriate reactive energy billing to aid system operation.

Classification by KPTCL of invalid VAR (injection during high voltage and

absorption during low voltage) is in line with grid operation requirements. However,

MVAR interchange should solely be dependent on voltages and not on power factor

alone.

Billing of reactive interchange presently is only with respect to drawal of MVAR,

irrespective of Voltage/ grid requirement.

Surcharge for injection of VAR at voltages greater than 103 % and drawal of VAR

when voltages are less than 97 % needs to be implemented.

Incentivization for absorption of VAR at voltages greater than 105 % and injection of

VAR at voltages less than 95 % may need to be considered.

SPDs/Wind Developers to be advised to absorb during night time also ( as also

demonstrated by M/s Adani).

Transformer Tap position to be optimized to help improve voltages at 400 kV.

Centralized SCADA operational control needs to be in place for reactive / scheduling

requirements.

SPDs/Wind Developers should support the grid as per set points advised by

SLDC/RLDC.

All states of SR (except Karnataka) have no tariff provisions for VAR exchange by

SPDs. Voltage based tariff provisions for VAR exchange needs to be introduced.

SRLDC had stated that earlier voltages were very low and it made sense to charge for

reactive drawl. Connectivity Agreement also states that at interface point there should not

be any reactive interchange. Injecting MVAR at high voltages was undesirable from grid

operation point of view. It is high time that this forum recommended to Regulators at


Central and State that reactive interchange should be as per voltage profile. Charges for

injection of VAR at voltages greater than 103 % and drawal of VAR when voltages are

less than 97% needs to be implemented.

APTRANSCO had thanked SRPC Secretariat and SRLDC for taking the initiative to

conduct trial test at Urvakonda and stated that their reports would strengthen their case in

the plea before Hon‟ble APERC. It is being proposed to waive off reactive charges

between 0.95 lag to 0.95 lead for wind and solar generators. Before proposing to APERC

it would be put up to APPCC (Discoms Board) on 13.08.2018 and after one week, they

would approach APERC.

It was pointed out that power factor based MVAR interchange may not bring out the

desired results (issues during night and during low RE generation). Therefore, voltage

based MVAR interchange coupled with specific powers to SLDC to direct MVAR

interchange as per grid requirement was needed.

NPC had informed that MVAR interchange in the grid should be on voltage basis and the

same is as per power system principles. This has been built into the Planning Criteria of

CEA. The same is specified in clause 14.2.2, „It shall be the responsibility of the

respective utility to bring the load power factor as close to unity as possible by providing

shunt capacitors at appropriate places in their system. Reactive power flow through

400/220 kV or 400/132 kV or 220/132 (or 66) kV ICTs, shall be minimal. Wherever

voltage on HV side of such an ICT is less than 0.975 pu no reactive power shall flow

down through the ICT. Similarly, wherever voltage on HV side of the ICT is more than

1.025 pu no reactive power shall flow up through the ICT. These criteria shall apply

under the „N-0‟ conditions‟.

APTRANSCO had agreed to consider and recommend MVAR interchange, based on

voltage.

KPTCL is planning to take up the recommendation to GoK to issue directions to KERC

to ensure that PPA / billing is in line with provisions of Grid Code (voltage based MVAR

interchange). Further, as per the Hon‟ble Supreme Court Order, PPA has to be aligned in

line with provisions of the Regulations.

TANTRANSCO had informed that testing at Kamuthi had been taken up on 09.08.2018.

On account of issues in inverter settings, there was improvement of around 1 kV only,

but retesting would be taken up.

NLDC had strongly recommended for voltage based MVAR interchange since it would

improve high voltage situation and enable keeping more lines in service. This would

improve reliability for RE evacuation and would avoid stress on switchyard equipment.

The same needs to be implemented at national level also.

CEA had informed that for 500 MW and above RE generators, active and reactive power

control as per the directions of the system operators is likely to come up in the

Amendment to Connectivity Regulations of CEA.

TSTRANSCO had informed that they are already taken up the requirements to be

incorporated in the State Grid Code (as had been suggested by SRPC Secretariat) with

TSERC.


TANTRANSCO and KSEBL had agreed in principle, and stated that they would take up

the issue with SERC appropriately.

Way forward in this regard was agreed in principle by all the constituents.

3.5 The following was noted in the SRPC Meeting:

Director General, NIWE informed that both Wind and Solar generators have a

capability of around 30 % of capacity as MVAR support. Tariff and commercial

mechanism is inhibiting their possible support. Further, the Regulations also talk

about active power control. NIWE is establishing testing facility for LVRT, HVRT,

active & reactive power control. All modern WTGs and inverters are capable of

supporting the grid in all respect. Only enabling Regulations as well as commercial

framework need to be in established. SRPC can take kindly note of it .

MS, SRPC informed the exercises carried out were without compromising with active

power. Technical capability had been established and with enabling regulations, PPA

conditions, ERC directions, MVAR support up to good extent could be achieved.

4. RAMP RATES

4.1 Ramp up and ramp down rates are assuming significance with higher level of RE

penetration, sudden changes in load, sudden PX schedules etc. Details of ramp rates of

RRAS stations are enclosed at Annexure-VI.

Regulation 7(4) of CEA (Technical Standard for Construction of Electrical Plant and

Electrical Lines states, „the design shall cover adequate provision for quick start up and

loading of the unit to full load at a fast rate. The unit shall have minimum rate of loading or

unloading of 3% per minute above the control load (i.e. 50% MCR)‟.

4.2 This issue had been discussed in the Meetings of OCC, wherein NTPC had pointed out that

for different make, same capacity units will be having different parameters. Also even for

same make of machines, the year of manufacturing also matters.

It was noted that Kudgi, NTPL and NTECL units had had come after 2010 and in case any

issue is being faced by generators in adhering to the Regulations, they may need to approach

CEA/Regulators. NTPC, NLC, NTPL and NTECL had agreed to discuss the matter with

their engineering division and try to improve the ramp percentages.

4.3 ISG stations under RRAS have started giving at least a ramp of 0.5%/minute which was

implemented from 16.06.2018. This had resulted in an increase in ramp of around 262

MW/block. SRPC vide letter dated 03.07.2018 (Annexure-VII) had taken up the issue of

providing ramps in the range of 1% to 1.5% /minute with NTPC, Ramagundam.

4.4 SLDCs should also ensure the enhanced ramp rates from the state generators. All units

irrespective of control area jurisdiction/ownership need to contribute with higher ramp rates.



NTPC had informed that at Ramagundam as per data available 0.66% was possible and it

would be implemented. Higher ramps would be tested and may be adopted in future,

since it may require more controlled operation. For other NTPC stations like Simhadri,

Kudgi and Talcher, the matter would be considered appropriately. 0.66 % would be

tested at Simhadri also.

NLCIL had stated that due to technology issues, they were constrained to restrict the

ramps. At TS-II Expn for ramping down, there was an issue since heat content remains

even after tripping of the boiler as 40-50 MW can be generated. However, they would

take up the issue with OEMs for increasing of the ramp rates.

CEA had informed that both in technical specifications as well as Regulations, it has been

mentioned that ramp rates of 3% needs to be ensured. CEA‟s Regulations were

applicable to units of Central and State and also the IPPs.

NPC had pointed out that units need to meet requirements specified for TE clearance and

also specified in the Regulations subsequently. Further, forum could consider possibility

of a mechanism that could be in place for self-improvement in ramp rates by generators.

NLDC had informed that ramps as informed by generators were being implemented

under RRAS. Ramp rate being furnished by generators needs to be examined wrt design

ramp rate as per CEA‟s Regulation. NLDC had assured that this issue would be taken up

with ISG stations at all India level.

SRLDC had pointed out that the demand rates and the RE injection/withdrawal was

within 3,000 MW/block. But as per estimate, once SR touches 4,000 MW

variation/block, present ramp rates would not suffice. Higher ramp rates in both the

direction were very much required.

PCKL had pointed out that more clarity on the ramps was required since there were

certain discrepancies in the Regulations / Technical Specifications. Higher ramp rates

were very essential in the present high RE scenario.

TCC had concluded that the ramp rates needed to be increased considering high

level of RE penetration. State sector / IPP generators were requested to kindly

improve ramp rates and SLDCs were kindly requested to implement the same.

NTECL, NTPL and NLCIL had agreed to consider increasing the ramp rates in both the

directions.

TCC had suggested that a Committee may look into provisions with regard to ramp

requirement as specified in various Regulations / specifications and expert advice of

CEA/NLDC may also be sought.

4.6 The following was deliberated in the SRPC Meeting:

SRPC agreed on TCC‟s suggestion that provisions with regard to ramp requirement as

specified in various Regulations / specifications could be looked into by a Committee.

Chairperson, SRPC suggested that advice and guidance from CEA could also be

sought.


Member (GO&D), CEA kindly agreed to appraise the concerned Division, in this

regard.

SRPC noted the TCC observation that ramp rates need to be increased,

considering high level of RE penetration. State sector / IPP generators were

requested to kindly improve ramp rates. SLDCs were also kindly requested to

examine and implement the same.

5. PROCUREMENT OF POC SOFTWARE FOR DISCOMS

5.1 TANGEDCO vide letter dated 24.05.2018/22.06.2018 had informed that in the 4th

Meeting

of the Task Force on „Review of PoC in ISTS‟, it had been decided that PoC software may

be purchased at RPC level for states (extract copy enclosed as Annexure-VIII) SRPC vide

letter dated 04.06.2018 had informed TANGEDCO that the matter regarding procurement of

software at RPC level would be taken up in the next meeting of SRPC. In the 38th

Meeting

of Commercial Sub Committee held on 29th

June 2018, it was agreed that the matter would

be discussed in the ensuing meetings of TCC and SRPC.

5.2 IIT Mumbai is the developer of the PoC software identified by Hon‟ble Commission. IIT

Mumbai had informed that they will provide software for computation of sharing of inter-

state transmission charges and losses, delivered as a web-service from PowerAnser Labs

(PAL), Department of Electrical Engineering, IIT Bombay for one year. The web-service

will be in compliance with the CERC (Sharing of Interstate Transmission Charges and

Losses) Regulations, 2010, L-1/44/2010- CERC, dated 15th

June 2010 and amendments

thereof. The fee for one year usage of one (1) Institutional Licenses which will include ten

(10) user logins each will be as follows:

One Year usage fee: Rs. 32,20,000/- (Rupees Thirty Two Lakhs Twenty Thousand Only)

plus applicable GST

Ninety (90%) percent + applicable GST to be paid in advance

Balance ten (10%) percent + applicable GST to be paid at the end of the year.

5.3 The following had been concluded in the TCC Meeting after deliberations:

Chairperson, TCC had stated that at present the data provided by NLDC appears to be

adequate. However, states may take a call individually, in case they so desire, and

approach IIT, Mumbai in this regard.

5.4 SRPC noted the above.

6. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE

6.1 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.


6.2 Subsequently, Chairperson, SRPC vide letter dated 12.12.2017 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).

6.3 Based on further discussion with M/s GIZ, the TOR had been refined and following scope

was agreed:

Control Reserve Dimensioning for States in Southern Region

Ancillary Services from RE and controlling RE generation during grid contingency

6.4 Further, M/s GIZ vide mail dated 03.07.2018 had informed that they had started the

procurement process. As they had to go for competitive tendering it would take about 3

months before they could sign contract with the Consultant.


7. MONITORING OF SCHEMES FUNDED FROM PSDF

7.1 In the 7th

Meeting of NPC held on 08.09.2017, RPCs had been further requested to examine

the implementation of PSDF funded schemes in OCC & TCC meetings and intimate NPC

about any bottlenecks.

7.2 In the 6th

Meeting of the Monitoring Group of PSDF held on 05th

January 2018 at Kochi, it

was observed that the overall progress was 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.


Overall status of schemes in SR as on 31st July 2018 is as given below:

S.

N

o.

State /

Entity

Total

No

of

prop

osals

Under

Approval

Not

eligible

San

ctio

ned

Grant

sanctioned

(Rs.

Crores)

Grant

Disburse

d

(Rs.

Crores)

Recen

tly

receiv

ed

Input

sought

1 Andhra

Pradesh

8 2 1 1 4 314.53 29.55

2 Karnataka 6 0 3 0 3 205.06 44.97

3 Kerala 7 0 0 1 6 581.8 166.15

4 Tamil Nadu 16 2 10 0 4 459.39 41.03

5 Telangana 12 0 6 1 5 247.72 49.93

6 Puducherry 2 0 0 0 2 13.19 0.95

7 PGCIL-SR 1 0 0 0 1 378.04 37.80

8 SRPC 2 0 0 0 2 30.59 19.01

Total 54 4 20 3 27 2230.32 389.39


In the OCC Meeting, Director, NPC had stated that there had been delays in signing of

Agreements and availing first 10 % installment, while subsequent releases had been

meager. Approved projects getting delayed beyond one year may not be eligible for

PSDF funding.

NPC had informed that at time of Kochi meeting the total disbursement was Rs. 161.8

crores while presently it was around Rs. 389.4 Crores and thus SR has certainly

progressed. This is around 17% of the grant sanctioned to SR. Kerala is progressing well

while other states need to put more efforts. Even 10% amount was not being availed by

some entities. In October/November, another round of follow up/review meeting is being

planned for SR constituents. Due to non-availing of the earlier sanctioned funds, MoP

was not releasing funds as per budget demand.

KPCL was requested to revert back on clarifications sought on DPR of Rs 156 Crores for

Modernization and Up-gradation of Control and Protection System at their Generating

Stations.

APTRANSCO had informed that PO has been placed for Reliable Communication

scheme (Rs 144 Crores) and the amount would be claimed soon. For other schemes also,

PO is under process.

TANTRANSCO had pointed that only after erection, balance 60 % is being released.

Orders for all the proposals had been placed and 20 % grant has been received. About Rs

90 crores of work is under commissioning and Rs 41 Crores would be availed within 2

months. PO for Reliable Communication scheme of Rs 139 crores is going to be placed

shortly.

KPTCL had informed that OPGW scheme was recently sanctioned, SAMAST scheme

observations would be replied back. NPC had informed that certain inputs had been

sought for SCADA scheme and the reply could be expedited by KPTCL.

KSEBL had informed that work has been nearly completed for the first scheme, but

extension was granted upto July 2018 which may need to be further extended by 3

months due to severe floods in the state. Rs. 30 Crore claim had been made which is to

be disbursed and the final claim of (Total Rs 47 Crores balance) would be made after the

works are completed, as and when water recedes. For the ADMS scheme, second claim

of 20% was pending for disbursement. Other schemes are also in the pipeline.

NLDC had stated that once the LOA had been placed, schedule needed to be followed up

vigorously. Time schedules are getting extended and extension approval getting delayed

since Appraisal Committee was not meeting frequently, resulting in delay in payments.

Getting the funds released from MoP takes around 3-4 months. Inputs sought by Techno

Economic Group also needed to be expedited for early sanctioning of DPRs.

NPC had informed that time extension approval was pending for a number of schemes. A

week before, procedure had been finalized to handle and process requests for time

extension. The procedure is for helping and facilitating the time extension requests. All

entities were requested to kindly furnish any time extension request within 15 days as per

this procedure.

SRPC had suggested that a senior Officer in each state may act as a Nodal Officer and


monitor the progress of PSDF funded schemes regularly, for better and effective

implementation.

It was agreed that periodical monitoring of PSDF funded schemes would be undertaken

at Senior Management level in each state.

7.4 SRPC noted that periodical monitoring of PSDF funded schemes would be undertaken at

Senior Management level in each state.

8 TRANSMISSION CHARGES / SHARING RELATED ISSUES

8.1 The issue of Transmission charges / sharing had been discussed in the Commercial Sub

Committee Meeting. Chairperson, SRPC vide letter dated 03.07.2018 (Annexure-IX) had

taken up the following issues with Chairperson, CERC:

a) Determination of Relinquishment Charges

Early resolution of Standard Capacity and relinquishment charges which are already

under kind consideration of Hon‟ble Commission in Petition No 92/MP/2015 would

help relieve the financial stress on DICs.

b) Transmission charges related with RE projects

The issues involved in implementation of policy regarding waiver of transmission

charges for solar evacuation under POC mechanism had been earlier taken up vide

letter dated 23.08.2017. The issue had been referred to the Task Force.

c) Recovery of Transmission Charges for delay in commissioning of SPDs

It was noted that there was a time gap between issuance of provision of Tariff Order

and Final Tariff Order. During this interim period, the charges are recovered through

POC mechanism from existing DICs, thus, causing upfront financial burden.

8.2 TANGEDCO vide letter dated 02.07.2018 (Annexure-X) had raised the following issues:

a) Issues associates with sharing of transmission charges by IPPs

It had been pointed out that Hon‟ble CERC in every tariff order directs to recover the

transmission charges as per the provisions of Sharing Regulation. The Clause (5) of

Regulation 8 of the Sharing Regulations stipulates as under:-

“(5) Where the Approved Withdrawal or Approval Injection in case of a DIC is not

materializing either partly or fully for any reason whatsoever the concerned DIC

shall be obliged to pay the transmission charges allocated under these regulations:

Provided that in case the commissioning of a generating station or unit thereof is

delayed, the generator shall be liable to pay Withdrawal Charges corresponding to

its Long term Access from the date the Long Term Access granted by CTU becomes

effective. The Withdrawal Charges shall be at the average withdrawal rate of the rate

of the target region:

In the referred case the defaulting DICs are the IPPs. Hence, the implementing

agency (NLDC) being responsible to implement the tariff orders and make PoC

computation is accountable to make the following points clear to the DICs for the

benefit of all concerned:

i. Whether the entire LTA quantum of the IPPs is considered for the purpose of

PoC calculation?


ii. Whether any clarification is obtained from Hon‟ble Commission with regard

to difficulties in implementing the orders related to the above IPPs?

iii. Any specific observation and comments of the validation committee on the

difficulties in implementing the orders.

iv. The details assets / LTA quantum to be considered for bilateral billing

furnished to SRPC.

Implementing Agency (NLDC) / CTU had been kindly requested to present their views.

b) Issues associated with transmission charges to be recovered from entities procuring

RE power and not qualified for waiver of transmission charges

MoP in its Order dated 13.02.2018 had communicated the waiver of inter-state

transmission charges and losses on transmission of the electricity generated from solar

and wind sources of energy under para 6.4(6) of the revised Tariff Policy, 2016. It had

been stated that in supersession of Ministry of Power‟s earlier order No.23/12/2016-

R&R dated 30th

September, 2016 and Order No.23/12/2016-R&R dated 14th

June,

2017, it is hereby notified that –

For generation projects based on solar and wind resources, no interstate transmission

charges and losses will be levied on transmission of the electricity through the inter-

state transmission system for sale of power by such projects commissioned till 31st

March 2022.

Provided that the above waiver will be available for a period of 25 years from the date

of commissioning till 31st March 2022.

Provided further that the above waiver will be available for solar and wind projects

entering into PPAs with all entities, including Distribution Companies for sale of

power from solar and wind power projects for compliance of their renewable

purchase obligation.

Provided further that the above waiver will be allowed only to those solar and wind

projects that are awarded through competitive bidding process in accordance with the

guidelines issued by Central Government.

This Order, irrespective of the purchasing entity, shall be applied prospectively ie from the

date of issue of Order.

CTU/NLDC had been kindly requested to elucidate on how this is being implemented.

c) Issues associated with recovery of transmission charges in respect of ultra mega solar

project at NP Kunta, Ananthapuram District, Andhra Pradesh

TANGEDCO has stated that the direction of Hon‟ble Commission in Order dated

30.06.2016 in petition No.26/TT/2016 should have been compiled by CTU and the IA.

The relevant portion of the order is extracted below:

51…………………….Accordingly the transmission tariff for the instant assets from the

date of commercial operation till the commissioning of solar generation shall be

borne by Andhra Pradesh Solar Power Corporation Pvt Ltd in line with the

Commission‟s order dated 06.05.2015 in Petition No.29/MP/2015. The relevant

portion of the order is extracted hereunder:-

„33…………….that transmission charges for delay in commissioning of solar power

generators are required to be paid by such solar generators/SPPD on the same line

as the liability for payment by the thermal and hydro generating stations in


accordance with the Central Electricity Regulatory Commission (Terms and

Conditions of Tariff) Regulations, 2014…………….‟

Subsequently Hon‟ble CERC in Petition No. 133/TT/2017 in the matter of Approval of

transmission tariff for ±100 MVAR STATCOM at NP Kunta Pooling Station under

“Transmission System for Ultra Mega Solar Park in Anantpur District, Andhra Pradesh-

Part A (Phase-I)…….” had passed Order dated 29.06.2018 wherein the following was

stated,

60. The Commission observed that as per the minutes of the 38th

SCM held on7.3.2015,

the CTU was to obtain clarification on the eligibility for LTA, connectivity, issue of

multiple injections, whether the sub-station which is in the premises of the solar park

should be under the scope of park developer or in STU/CTU and whether LTA should be

applied by actual generation developers who may sign PPA with AP DISCOMS or the

APSPCL and directed the petitioner to submit action taken and the clarifications

received.

61. In response, the petitioner vide affidavit dated 12.12.2017 has submitted that as per

CERC (Grant of Connectivity, Long-term Access and Medium-term Open Access in Inter-

State Transmission and related matters) Regulations, 2009 any company authorized by

the central government as Solar Power park developer (SPPD) can apply for

Connectivity/Long Term Access (LTA) in ISTS. MNRE vide its letter dated3.6.2015

authorized APSPCL as a SPPD to apply for connectivity/LTA in ISTS for its NP Kunta

Solar Park (1500 MW). As regards multiple injections, the petitioner submitted that

according to the Statement of Reasons to the above said regulations, in a solar power

park there may be multiple generation developers who may be injecting at various

points within the solar park and ultimately inject at interface with ISTS. Hence, it will

be treated as single injection at the interface point with ISTS. On the issue of whether

the sub-station within the solar park should be under the scope of park developer or

STU/CTU, the petitioner submitted that as per the Government of India (MNRE) letter

dated 12.12.2014, the responsibility of setting up a sub-station near solar park will lie

with the CTU or the STU taking into consideration the technical and commercial

requirement stipulated by the State and Central Commission.

62. TANGEDCO has submitted that in case of State specific solar projects there are no

identified beneficiaries outside the host State and there is no inter-State flow of power as

there is no firmed-up beneficiary outside the State. Further, the regulations do not permit

the socialization of the PoC charges among the beneficiaries of ISTS. TANGEDCO has

submitted that it has raised the issue of ambiguous procedure for implementation of the

waiver of the transmission charges for the solar and wind power under PoC mechanism.

63. TANGEDCO has submitted that the CERC (sharing of inter-State Transmission

Charges and Losses) Regulations, 2010 (2010 Sharing Regulations) did not account for

solar power injections into grid due to the capacity limitations and dispersal at

distribution level. As per the SOR of the 2010 Tariff Regulations, the 2010 sharing

Regulations facilitate solar based generation by allowing zero transmission access

charge for use of ISTS and allocating no transmission loss to solar based generation.

Solar power generators shall be benefited in event of use of the ISTS. Since such

generation would normally be connected at 33 kV, the power generated by such


generators would most likely be absorbed locally. This would cause no / minimal use of

400 kV ISTS network and might also lead to reduction of losses in the 400 kV network by

obviating the need for power from distant generators. TANGEDCO has submitted that in

contrast to the SOR, the present scenario is different as the solar power has attained grid

parity and the capacity is of the order of 1000 MW and above. This peculiar situation

necessitates revisiting the methodology for determining the PoC charges and the Sharing

Regulation. The sharing Regulations in the present form will only pass on financial

burden on account of the inefficiencies/inaccuracies in allocating the charges on to the

existing DICs irrespective of whether they are beneficial user or not. TANGEDCO is in

no way connected with the sharing of the transmission charges since it is neither the

beneficiary of the State specific solar project nor using the transmission lines. The power

generated and consumed within the State of Andhra Pradesh does not entitle levy of

transmission charges on TANGEDCO and hence the claim of the petitioner is not

maintainable.

64. In response, the petitioner in its rejoinder dated 28.12.2017 has submitted that

Ministry of Power, Govt. of India vide its letter No. 11/64/2014-PG dated 8.1.2015 while

dealing with the evacuation of power from nine solar parks (7020 MW capacity) being

set up in seven States including Andhra Pradesh Solar Ultra Mega Park observed that

the transmission line connecting solar parks to ISTS are to be declared part of ISTS and

PGCIL is assigned to take up construction of transmission line including pooling station

from solar generating parks on compressed time schedule basis. Further, the issue of

implementation of the transmission line for connecting the Solar Power Parks to the ISTS

was discussed in the 38th

meeting of the Standing Committee on Power System Planning

of Southern Region held on 7.3.2015 and it was agreed that the proposal was technically

in order and could be firmed up subject to resolving the regulatory issues. The scheme

was technically validated in the 38th

SCM and at Para 21.21 of the 38th

SCM following

submissions were made with respect to scheme and STATCOM. The scheme was also

deliberated in 27th

meeting of SRPC held on 12.05.2015 in presence of all Southern

region constituents. The Commission in order dated 6.8.2015 in Petition No. 29/MP/2015

accorded the regulatory approval for execution of the instant transmission. The petitioner

has submitted that the sharing of transmission charges for Solar Park at Ananthpur

district, Andhra Pradesh has already been decided by the Commission wherein it was

held that billing, collection and disbursement of transmission charges shall be governed

by the 2010 Sharing Regulations.

65. TANGEDCO has submitted that it has filed an appeal against the Commission’s

order dated 16.5.2016 in Petition No.26/TT/2016 before the Hon’ble Appellate

Tribunal for Electricity and it is pending disposal.

66. We have considered the submissions of the petitioner and TANGEDCO. We are not

able to agree with TANGEDCO that waiver of ISTS charges for solar and wind

generation is not in order. We are of the view that the waiver of transmission charges

for solar and wind generation is as per provisions of Sharing Regulations 2010 and is

in line with government policy to encourage renewable energy in the country.

Therefore, the billing, collection and disbursement of the transmission charges approved

for the instant asset shall be governed by the provisions of CERC (Sharing of Inter-State

Transmission Charges and Losses) Regulations, 2010, as amended from time to time, as


provided in Regulation 43 of the 2014 Tariff Regulations, subject to the outcome of the

Appeal filed by TANGEDCO before APTEL.

8.3 SRPC vide letter dated 04.07.2018 (Annexure-XI) had taken up the issue with CTU.

Implementing Agency (NLDC) / CTU had been kindly requested to furnish the views.


MS, SRPC had appraised the TCC about the issues taken up by Chairperson, SRPC

with Chairperson, CERC based on deliberations of Commercial Committee.

TANGEDCO had been raising these issues in various forums and had also gone in

appeal before Hon‟ble APTEL and thus matter is sub judice. Further the matter

regarding LTA operationalization of SPDs in accordance with Order for Petition No

26/TT/2016 had been taken up by SRPC Secretariat with CTU. CTU vide letter dated

09.08.2018 (Annexure-XII) had informed that LTA would be made effective with

commissioning of associated elements at NP Kunta, in phases. In case of NP Kunta, all

elements except NP Kunta – Hindupur were nearing completion. Operationalization of

part LTA/full LTA needs to be carried out periodically and possibly in consultation

with RPC constituents. This periodic exercise would help allay any apprehensions and

also instill confidence among these entities.

TANGEDCO had pointed out that NP Kunta issue had been raised by TANGEDCO in

CC Meeting and the billing needs to be carried out bilaterally as per CERC Order.

Further there was no provision for blanket waiver of transmission charges and losses for

wind and solar generators. The checks (in respect of three conditions) being carried out

by CTU/NLDC in this regard, needs more clarity. Implementing Agency needs to issue

guideline regarding sharing of charges by SPDs for delay in commissioning of

generating units. Regarding relinquishment, presently there were no clear guidelines

from Hon‟ble CERC with regard to recovery of these charges.

CTU had stated that it is a rolling exercise as and when generation and transmission

elements are added to the grid, and results would be shared with the RPC. All decisions

are being taken fully complying with the CERC Regulations and CERC Orders. There

are a number of similar cases and generators are paying the charges, as applicable.

Hon‟ble CERC is also reviewing status of LTA/part LTA operationalization.

TSTRANSCO had stated that there was a need for assessing that commercial activities

are in line with prevailing Regulations.

SR-I, PGCIL had observed that transmission elements for NP Kunta had been brought

after thorough consultation with APSPCL and NTPC and also discussion in SRPC

forum. Line from NP Kunta to Hindupur (including reactor at Hindupur) was ready

since February 2018 but APTRANSCO was facing certain ROW issues in completing

line from Urvakonda to Hindupur, because of which commissioning is getting delayed.

CTU had informed that for the delay in commissioning of the generation projects, the

cost would be recovered from SPDs/ SPPDs in accordance with CERC Order in

Petition no: 26/TT/2016.

It was agreed that a Special Meeting would be held with CTU, NLDC & SR-

Constituents to discuss the above issues. Issue regarding operationalization of LTA/


part-LTA would be discussed and would be supported with studies. Criterion in place

for waiver of transmission charges for RE-generators would also be discussed.

TCC recommended that Chairperson, SRPC may kindly be requested to take up the

issues again with Chairperson, CERC for addressing the concerns raised.

8.5 The following was noted in the SRPC Meeting:

Chairperson, SRPC suggested that the Committee may deliberate and come out with

some recommendations in consultation with PGCIL, and also the matter may need to be

taken up with Hon‟ble CERC.

9 OPTIMUM HARNESSING OF RE IN SOUTHERN REGION

9.1 Follow up of MoP/SRZC meeting

9.1.1 In earlier SRPC Meetings Tamil Nadu had been requested to kindly sign the Overarching

Agreement. SRPC vide letter dated 24.01.2018 had requested Chairperson, TNEB that

necessary directions may kindly be arranged be given to TANGEDCO for signing the

Overarching Agreement. In the 33rd

Meeting of SRPC, TANTRANSCO had stated that

before the next SRPC Meeting, the Overarching Agreement was likely to be signed for

Banking/Swap option.

9.1.2 MoP vide letter dated 18.06.2018 (Annexure-XIII) had sought update in respect of

„Optimum harnessing of renewable energy available in Southern States without

endangering the security‟ as noted in the 10th

meeting of the Standing Committee of

Southern Zonal Council held on 28.11.2017 at Bengaluru. It had been recorded,

„Government of Tamil Nadu stated that balancing of demand can be made with mutual

agreement among member States to (i) Standalone export: By which power could be

transferred from surplus State to deficit State without any obligation to return the power;

and (ii) Banking/Swapping of Power to deficit States on „Give and Take mode‟, returnable

to installments at a mutually agreed quantum, duration and time. It was stated that TN is

also considering signing an agreement after considering the issue of pricing‟.

9.1.3 SRPC Secretariat vide letter dated 27.06.2018 had furnished the update to CEA wherein it

was noted that the Overarching Agreement had been utilized as follows:

Date Seller Buyer MW and duration

28.02.2018 Karnataka Kerala 150 MW – 2.5 hrs

01.03.2018 Karnataka Kerala 200 MW – 04 hrs

21.05.2018 Karnataka Andhra Pradesh 300 MW – 03 hrs

9.1.4 MS, SRPC vide letter dated 27.06.2018 (Annexure-XIV) to Chairman, TNEB had

requested to kindly consider signing the Overarching Agreement and to avail opportunities

in real time operation and this also enclosed in the letter to CEA.

TCC deliberations


9.1.5 TANTRANSCO informed that they were considering signing of the Overarching

Agreement after obtaining necessary approval.

TN has entered for 900 MU of swap power exchange with other states.

9.1.6 SRPC noted the above

9.1.7 The following was noted in earlier Meetings with regard to SAMAST, while update in

TCC is given in italics:

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

CERC and to NLDC for funding.

APTRANSCO had informed that sanction has been received.

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

TSTRANSCO had informed that the matter was being followed up.

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

project was likely to be completed by 25.05.2018.

TANTRANSCO had informed that it was moving ahead.

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

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

KPTCL had informed that reply to observations would be furnished.

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).

9.2 Pump Storage Plants

9.2.1 The following is the status of upcoming Pump Storage Plants in SR:

State PSP Scheme Status

Andhra Pradesh Sileru (6 x150 MW) Recommended to

MoEF&CC for granting

Environmental Clearance

Tamil Nadu Kundah (4 x125 = 500 MW) 42nd

SCPSPSR : 2020-21

33rd

TCC: All the statutory clearances required for the

project have been obtained. EPC contracts for

establishment of packages I & II of phase I of this project

relating to Civil and Hydro mechanical works have been

awarded on 15.02.2018. Due to no response for the tenders

floated for Package-III of Phase-I, Phase II & Phase III

(E & M works) retendering is being processed. This Project

is expected to be commissioned in 2021-22.

Sillahalla-I (4x250 = 1000

MW)

42nd

SCPSPSR : 2023

onwards


33rd

TCC: The First Stage (1000 MW) with the proposed

Sillahalla reservoir as upper Reservoir and a new

reservoir below the existing Kundah Paalam & Kundah

Power House I as lower reservoir is to be taken up. Tender

for Consultancy services towards preparation of DPR for

the Stage –I of this project has been floated.

Preliminary works are under progress. The project is

expected to be commissioned in the year 2024.

Sillahalla-II (4x250 = 1000

MW)

42nd

SCPSPSR : 2023

onwards

33rd

TCC: To be taken up later.

4 projects on existing sites

33rd

TCC: Manalar PSHEP (500 MW) and Kodayar

PSHEP (500 MW) are in preliminary investigation stage.

The other two PSHEPs are found to be not much suitable.

Further investigations are under progress.

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)

9.2.2 APGENCO vide letter dated 03.08.2018 (Annexure-XV) had requested for

recommending 6 x 150 MW Pumped Storage Sileru Basin to MoEF&CC for granting

Environmental Clearance on priority basis.

9.2.3 The following had been noted in the TCC meeting:

TCC had recommended that MoEF&CC be kindly approached for granting

Environmental Clearance on priority basis to 6x150 MW Pumped Storage Sileru

Basin.

TCC had requested the entities to expedite the identified pumped storage schemes on

priority.

9.2.4 SRPC noted the above.

10 ISSUES WITH OA CONSUMERS

10.1 In the OCC Meetings, it was noted that some OA consumers are directly approaching Power

Exchange for short duration of time when PX rates are less and during other times they were

availing power from the DISCOMs.

10.2 During last year KSEBL had suspended NOC of such consumers but OA consumers had

approached KERC and High Court with the prayer that NOC cannot be rejected on account

of lower demand. High Court had directed KERC to give a solution and Commission had

stated that NOC can be rejected only if there are transmission constraints.


10.3 OCC Members had informed that the following modalities / procedure for granting OA to

consumers in states like Gujarat, Rajasthan and Himachal Pradesh to mitigate this problem

as given below:

OA is granted on RTC basis and not for few blocks during the day.

Once consent is granted for OA, the consumers have to compulsorily purchase

through OA.

For taking consent for OA for any particular day, the application filed by the

consumers two days in advance. For taking OA for the whole month, the consumers

have to file the O.A. application by the 15th

of the previous month.

Such conditions have helped the Discoms to assess the demand supply in a more

efficient manner.

It was suggested that the best practices of different states could be studied for further

finalizing a procedure / guideline which could be implemented in the states after due

approval of the SERCs.


SRPC had presented the practices being followed in this regard in Rajasthan &

Gujarat (Annexure-XVI). Crux was that OA was permitted for the whole day and not

for intermittent blocks. For 8 hours, uniform schedule was to be maintained and

minimum schedule was to be at least 75 % of the max schedule. This was required so

that supply planning by the Escoms is carried out in a more efficient manner.

KSEBL had informed that Kerala faces typical problem that whenever demand is

crashing, OA consumers are going to the market for large quantum and for that huge

generation backing down is to be resorted to. SLDC was forced to curtail OA during

such exigencies. OA consumers had gone to SERC & High Court and the SERC had

passed the Order that low demand cannot be a reason for OA curtailment. Gujarat OA

conditions were informed to SERC, but SERC is waiting for OA quantum to increase

to consider any amendment.

APTRANSCO had observed that whether any tweaking of OA Regulations would be

violation of the EA provisions. Only two conditions are to be satisfied - metering and

transmission capacity.

It was opined that non-discrimination means that the utility should not discriminate

among OA consumers but it does not mean that certain reasonable conditions cannot

be imposed. OA in its present form affects the planning process of Discoms to meet

the demand since OA demand is already considered by them. Subsequently, it may get

replaced and thus that much margin is always to be maintained by the Discoms.

TSTRANSCO had opined that there should be advance intimation by OA consumers

on the quantum being availed through state utilities.

PCKL had pointed out that Distribution Licensee & OA consumers are to be viewed

on different parameters and whether different DS Mechanism is required for OA

consumers‟ needs to be examined.

It was agreed that Chairperson, SRPC would be kindly requested to take up the issues

raised by Constituents with MOP.


10.5 SRPC requested Chairperson, SRPC to kindly to take up the issues raised by Constituents

with MOP.

11 PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER

ENVIRONMENT (PROTECTION) AMENDMENT RULES, 2015

11.1 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, 1st Jan 2004 to 31

st December 2016 and beyond 1

st January 2017. Existing

as well as new plants were required to meet standards by the stipulated time lines.

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

SRPC as well as Subcommittee Meetings

11.2 The following had been noted in earlier Meetings:

SRPC had noted the requirements for necessary compliance.

Chairperson, SRPC vide letters dated 24th

May 2017 & 28th

August 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.

In view of the time bound nature and its criticality Chairperson, SRPC vide letter dated

04.10.2017 had requested Chairperson, CERC that the concerns expressed by the

generators may kindly be arranged to be examined.

11.3 As discussed in the 33rd

Meeting of SRPC held on 17.02.2018, Chairperson, SRPC vide

letter dated 02.03.2018 (Annexure-XVII) had requested that MoP to bestow its kind

attention on the matter regarding funding; either from PSDF or any other fund, to meet the

stipulated revised environmental norms.

11.4 A Special Meeting had been convened at SRPC Bangalore on 23.02.2018 (Minutes

available on SRPC website) to discuss on incentive to TTPS for early installation of

Pollution Control Equipment.

11.5 MoP vide letter dated 30.05.2018 (Annexure-XVIII) had finalized „Mechanism for

implementation of New Environment Norms for Thermal Power Plants (TPP) supplying

Power to distribution licensees under concluded long term and medium term Power

Purchase Agreement (PPA)‟. In the Mechanism, it has been stated, „After considering all

aspects and with due regard to the need for safeguards against environmental hazards and

accordingly to ensure timely implementation of new environment norms, the Central

Government has declared that –

5.1 The MoEFCC Notification requiring compliance of Environment (Protection)

Amendment Rules, 2015 dated 7th

December, 2015 is of the nature of Change in Law

event except in following cases:


a) Power Purchase Agreements of such TPPs whose tariff is determined under Section

63 of the Electricity Act, 2003 having bid deadline on or after 7th

December 2015, or

b) TPPs where such requirement of pollutions control system was mandated under the

environment clearance of the plant or envisaged otherwise before the notification of

amendment rules.

5.2 The additional cost implication due to installation or up-gradation of various emission

control systems and its operational cost to meet the new environment norms, after

award of bid or signing of PPA as the case may be, shall be considered for being made

pass through in tariff by Commission in accordance with the law.

5.3 The respective TPPs may approach the Appropriate Commission for approval of

additional capital expenditure and compensation for additional cost on account of this

Change in Law event in respect of the Power Purchase Agreement entered under

Section 62 or Section 63 of the Electricity Act, 2003

5.4 For the TPPs that are under the purview of the Central Commission, the Commission

shall develop appropriate regulatory mechanism to address the impact on tariff and

certainty in cost recovery on account of additional capital and operational cost, under

concluded long term and medium term PPAs for this purpose.

11.6 SRPC Secretariat vide letter dated 25.06.2018 (Annexure-XIX) had forwarded CEA‟s

letter seeking updated information in respect of status of implementation of the revised

FGD installation / ESP upgradation plan to comply with the new environment norms.

Updated information is to be communicated periodically (initial update was to be

furnished by 30.06.2018).


TANGEDCO had stated that they had already furnished their comments that

expenditure towards compliance of MoEF rules may be decided on average PLF, age

and benchmark norms to be finalized by CEA. It is seen that many old Thermal Plants

are in service beyond the life span. Therefore compliance in all cases may not be

necessary considering level of RE penetration in TN and also shortage of domestic coal.

It was noted that units need to necessarily comply with the norms as per the CPCB

timelines.

Generators had noted the MOP directive dated 30.05.2018 on „Mechanism for

implementation of New Environment Norms for Thermal Power Plants (TPP) supplying

Power to distribution licensees under concluded long term and medium term Power

Purchase Agreement (PPA)‟.

CPCB timelines for the compliance of environmental norms were also noted by the

generators (enclosed as Annexure-XX).

PCKL had pointed out that there has to be some measure and check on the pass

through, commensurate to the environmental concept and the same is being suggested

to KERC.

It was noted that this is a monitored activity by Hon‟ble Supreme Court and by

Government through CEA and hence regular updates need to be communicated. The

timelines of CPCB need to be strictly adhered.



12 COAL ISSUES

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

the past few months. The following had been noted in earlier Meetings:

Chairperson, SRPC vide letters dated 25th

September 2017 and 13th

November 2017

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 had raised energy security concerns with

Hon‟ble CERC and had 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.

As agreed in the Secunderabad Meeting held on 21st December, Chairperson, SRPC

vide letter dated 28th

December 2017 had taken up the issue regarding „Consent of

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

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.

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. For Unit 6 at Rayalaseema (Stage IV) additional 2 rakes/day

were required for movement of raw coal from MCL for this purpose.

KPCL had informed that around 18 rakes/day would be required 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.

The logistic constraints between Sambalpur-Rayagada and the congestion between

Vizianagaram and Vizag were noted.

MCL had pointed out that Availability of BOXN rakes (in ECR and ECOR) for long

distance linkage power plants are to be improved. 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. Congestion in ECO Railways, for rakes

going to Paradip and through Sambalpur – Titlagarh route was 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. 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. MCL had requested Gencos for

clearing of the dues to MCL in a timely manner.


12.2 As agreed in 33rd

Meeting of SRPC, Chairperson, SRPC vide letter dated 20.02.2018

(Annexure-XXI) had taken up the concerns of SR Thermal generators with Chairman,

Railway Board.

12.3 MD, APGENCO vide letter dated 08.06.2018 (Annexure-XXII) had taken up the issues of

transportation of raw / washed coal from MCL to APGENCO power plants by ARR with

Railways. The daily requirement has been specified as 2 rakes/day from BBMT siding &

3.2 rakes/day for Dr NTTPS, 1.33 rakes/day for RyTPP and 2 rakes/day for RyTPP stage-

4.

12.4 NTPL vide letter dated 31.05.2018 (Annexure-XXIII) had requested CEA to review the

criteria of criticality for NTPL coal stock position as 20 days for critical and 9 days for

super critical so as to improve the allocation of coal companies and rakes by railways.

12.5 NTECL vide mail informed that around 233 MU had been lost (in DC Declaration) from

01.04.2018 to 21.05.2018) (Annexure-XXIV).

12.6 SRLDC had prepared a link where the details of coal were to be uploaded

(https://goo.gl/y3LL4n). This information needs to be furnished before 06:00 hours every

day (critical since information is shared with MoP).

12.7 APGENCO vide letter dated 5th

July 2018 (Annexure-XXV) had informed that they are

getting 2 to 3 grade slippages particularly in case of coal received from Manuguru and

Rudrampur mines for RTPP and Dr NTTPS stations. This is despite constant pursuance

with SCCL and CIMFR.


It was noted that there was loss in DC of around 394 MW during July 2018 out of

which 323 MW was from Talcher-II station, alone.

NTPC had informed that the loss in DC was due to issues at MCL (strikes etc) and

prominently due to very poor quality of coal. The issue had been taken up with MCL

and officials had been stationed at mines to ensure that coal quality improves.

KSEBL had pointed out that for Talcher II, DC during peak hour was less than other

hours on some of the days.

APTRANSCO had stated that monsoon would recede by mid-September and adequate

DC availability needs to be ensured by generators.

PCKL had stated that the coal stock position also needs to be considered in Merit Order

Despatch.

It was noted that OCC had suggested that less than three days of coal stock could be

considered as fuel shortage conditions. ISGS need to ensure that in case average DC is

less than ex-bus (normative) over a day, then DC would need to be maximized during

https://goo.gl/y3LL4n


6-9 hours and also during 18-21:30 hours, while appropriately reducing DC during

other hours. TCC observed that the same needs to be followed.

It was noted that the issues would be discussed further in the SRPC Meeting where ED

(Coal), Railways, HOD (M&S), MCL & ED (CM), SCCL had confirmed their

participation.

12.9 Coal Supply Issues

MCL stated they were maintaining overall materialization of coal at 79 % in FY 2018-

19. For South bound power plants it had been 64.6 % in 2016-17 and 71.5 % in 2017-18

while upto July 2018 (FY 2018-19) it was 77 %. There has been a continuous growth in

materialization of South bound power plants. Some of the plants of MAHAGENCO and

RGHPGCL were getting coal only up to 65 %. MCL had to optimize supply to all the

link plants and not just to specific plants.

NTPC-Talcher stage-II

MCL stated that upto 08.08.2018 in this FY, around 98 % contracted capacity had been

supplied to Talcher Kaniha plant. Since Talcher had been supplied the linkage quantity,

the remarks on coal supply may need to be reviewed.

NTPC informed that in the month of July 2018 for around 25 days, the quality of coal

supplied was quite poor and the specific coal was in the range of 1 kg/kwh. There had

been reported strikes and instances of rain water entering the mines during that period.

On 23rd

, 24th

, 27th

and 30th

, only slurry had been supplied.

MCL informed that there had been heavy rain during 2nd

half of July 2018 which was

622 mm around Sambalpur, Raigad, Cuttack, Bhubaneshwar & Paradip. Even some of

the mines had been submerged. Despite these constraints, the supply had been ensured.

In the month of August 2018 the materialization was 108% in respect of NTPC, Kaniha.

It was assured that the coal would be supplied as per the requirement. MCL had been

requesting NTPC to avail coal from Ib sidings. Earlier NTPC was picking 2 rakes from

Ib siding which had been stopped in July 2018. NTPC needs to supplement by taking

additional rakes from ECL, and this would ensure higher generation levels also. This

suggestion had also been made to NTPC in the Sub-group meeting. Earlier additional

coal was being given to Talcher; Kaniha for getting performance incentive. But from

2017-18, NTPC has rationalized incentive for overall FSA, adversely affecting MCL‟s

incentive. Incentive on supplying coal to local plants needs to be relooked by NTPC.

NTPC informed that NTPC had not questioned the quantity of the coal but there were

issues in the quality. In the coming months, with depletion of rain the situation was

likely to improve. Other issues of availing coal from ECL / Ib would be examined as

there were cost implication also (ECL cost high) and same would be communicated to

the concerned division in NTPC Corporate.


APGENCO

MCL / APGENCO informed that FSA for 2.778 MTPA for Rayalaseema Stage-IV had

been completed on 20.07.2018 and the coal supply had started.

MCL informed that in April 2018 as part of its initiative (to go to door step of

consumers) they had held a meeting with the APGENCO / APPDCL and AP power

plant along-with Vizag Port and Railway officials at Vizag. Power Stations had been

requested to avail some coal through Vizag Port. Parallel channels need to be utilized so

as to ensure that requirements are met. New Sardega siding at MCL had been added and

around 5-6 rakes/day could also be loaded from there. It is a new siding of South East

Railways. Generators were requested to have agreement with SE Railways (HQ

Kolkata) for enhanced rake movement towards Damra and Haldia Ports.

KPCL

KPCL informed that price structure proposed by SCCL for 4.89 MT is higher compared

to normal mine rates under FSA & CIL price. Offered quantity is less than requirement

of 90 lakh MT per annum (for RTPS and BTPS). Signing of FSA was to be as per

FSA/linkage terms and conditions at notified price (MOC had directed SCCL and KPCL

to sign FSA in its meeting dated 10.4.2018).

SCCL informed that they had already informed KPCL through letters regarding the price

structure and quantity offered as per MoC policy and as per SCCL Board directives.

SCCL had also informed that KPCL is yet to come forward for signing of FSA as per

SCCL proposal.

MCL informed that materialization in respect of Raichur was 103 % in 2016-17 and 109

% in 2017-18 while in 2018-19 (upto July 2018) it was 134 %. Additional coal of

around 2 LT/month was being taken from MCL by KPCL. Proper mix of ARR and RSR

should be ensured by KPCL and it should be practical. It was suggested to take more

coal from Ib field. Most of the stations were requesting more coal from Talcher which

may not be possible and thus other options of getting coal from Ib etc needs to be

exercised.

TANGEDCO

MCL informed that additional supply of coal of 0.5 MTPA (earlier being supplied by

WCL) had been formalized for TANGEDCO.

TANGEDCO observed that some of the MCL coal was being moved to Vizag Port.

However, at Vizag Port there was no mechanical unloading and thus all was under

manual unloading. Cost of unloading at Vizag Port was much higher compared to

Paradip Port so they are not able to divert their coal to Vizag Port.

MCL stated that TANGEDCO was already having multiple avenues; coal was being

taken through ARR for Mettur and through Paradip, Vizag and Haldia Ports. Vizag Port


in the meeting held in April 2018 had assured of package (merit order benefit, discount

etc) to the power plants which could be availed.

NTECL

MCL informed that they were in touch with NTECL for any additional requirement of

coal in the coming months.

NTECL informed that they were willing to avail more coal from Sardega siding of

MCL, but there were some issues regarding weighment.

NTPL

NTPL informed that they are getting good support from MCL (95 % realization up to

July 2018). From September 2018, additional quantity would be required.

MCL

MCL stated that the utilities (APGENCO, APPDCL and NTPL) availing coal through

Washery mode should ensure that the Washery operators pickup sufficient raw coal in

time. Lifting of coal by Washery has been poor. Utilities can take up the issues with the

Railways for lifting washed coal from Washery.

Most of the South bound stations taking coal through Paradip Port should also consider

increasing off take at Damra and Vizag Ports to improve materialization.

12.10 Grade Slippage Issues

APGENCO had informed that 2 to 3 Grade slippages between loading end of SCCL and

unloading end (from Manuguru and Rudrampur mines) for RyTPP and Dr. NTTPS

(Vijayawada TPS) was an issue of concern. In last two month‟s atleast 2 to 3 Grade

slippages had been observed.

SCCL informed that representatives from Gencos / NTPC were being allowed as per the

Tripartite Agreement and they were extending all necessary facilities to representatives

at the loading points. At the loading point all the three parties were present and hence

SCCL was not responsible for any reported grade slippage at the unloading point.

Specific two areas had been mentioned by APGENCO and SCCL would look into this

issue.

APGENCO observed that officials/representatives of APGENCO were not being

allowed at the loading point.

MD, APGENCO noted that Grade slippages were affecting the generation besides the

cost also. Normally, whatever quality and quantity of coal is loaded only reaches the

plant and hence variations are minimal. In a nutshell, whatever is loaded should be

billed. There is a need for a transparent mechanism to sort out loading / unloading Grade

slippage issues.


SCCL informed that the issue of the Grade slippages between loading and unloading

point also needs to be sorted out by CIMFR.

MCL informed that the Grade slippage was getting addressed and only 27 % of the

supply was getting downgraded while 73% supply was being upgraded. Even the 27%

issue would be looked into and rectified.

NTPC observed that at Ramagundam the loading point is only 8 kms away (15 minutes

delivery time) and that through MGR and even there 2 Grade slippages have been

reported. Representatives and cameras are not being allowed by SCCL. Auto sampler

has not been installed/not working at SCCL. Same CIMFR is doing sampling at both the

ends and still the Grade slippages are being observed. Issues at loading end needs to be

addressed by coal companies and the unloading issues would be taken care by the

stations.

NTPL informed that MCL had resolved the Grade slippage issues and other coal

companies need to fall in line. Grade slippages were being observed in ECL supply also.

They were getting invoice for G11 while the supply was G15.

PCKL pointed that 2 to 3 Grade slippages was having significant impact on GCV and it

translates into about 600-900 Kcal/ Kg loss which has to be borne by the consumers.

TANGEDCO observed that CIMFR was sending the quality reports after 2 months,

CCL & ECL reports were not being received and the payment was made in advance (1st,

11th

and 21st) and subsequently only the quality linked payment (Grade slippage) was

being factored in. Reports by CIMFR needs to be expedited to ensure payment

curtailment in a timely manner. The advance quantum would also get reduced

considerably.

Chairperson, SRPC concluded that in the interest of the consumers, coal companies need

to come out with a transparent mechanism, besides third party sampling. Importance of

Third party sampling at unloading point could also be examined. Cameras and

representatives could be allowed to improve the confidence levels of the stations

towards quality and quantity. SCCL and other coal companies could take the lead from

MCL on addressing the Grade slippage issues which could be discussed in the next

meeting. CIMFR officials could also be invited in the next Meeting.

12.11 Railway issues

Railways

It was informed by Railways that materialization of All Rail Routes (ARR) from

Talcher had been less in the last 3 to 4 months due to the need for higher deployment of

BOXN rakes for carrying coal to power houses in North India and West India. This was

necessitated due to closure of some Port based power plants (run on imported coal) in

Mundra and Essar Ports which had resulted in shortfall of 3,000 to 4,000 Megawatts.


The power plants in Haryana, Gujarat and Rajasthan had been fed extra 20 rakes per

day from CIL sources. The materialization for BOBR circuits from Talcher was

satisfactory. It was also informed that a large number of BOXN wagons were being

inducted (8,000 to 10,000 wagons) in the current financial year which has improved

BOXN rake availability and helped in improving the ARR materialization from

Talcher.

Railways have close coordination with MoP and MoC and they are meeting nearly on a

daily basis. For stations featuring in super critical / critical coal stock, special

arrangements were being made to improve the coal supply. In addition, there was a

fortnightly Meeting between Secretary (P), Secretary(C) and Member (Traffic) and

issues are discussed with Power Plants and Zonal Railways. Critical coal stock stations

come on radar and issue is resolved on priority. Most of the plants in SR are more or

less comfortable except few plants like Kondapalli (Vijayawada) which have come

recently under critical coal stock. Rains have impacted loading all over, WCL and ECL

are badly affected and MCL and Railways‟ mobility were also impacted. Stations don‟t

release the wagons in a timely manner and the issues of sticky coal, CHP getting

jammed etc leads to lesser rake availability.

Railways informed that preferred movement from Sardega siding of MCL was towards

Damra and Haldia and not towards Paradip.

Railways assured the forum that they were in touch with all the utilities on day-to-day

basis and issues are being resolved.

NTPC-Talcher, Kaniha

Railways informed that one rake/day was being moved from ECL and because of rains

the loading at ECL had gone down. Presently around 10 rakes/month were coming, and

as and when ECL loading picks up, the supply would increase.

NTPC - Simhadri

NTPC Simhadri stated that though MCL was offering coal, there were some issues in

allocating higher number of BOBR rakes to Simhadri by the Railways. BOXN rakes

were taking longer time to unload.

Railways clarified that supply to Simhadri would be a combination of BOXN and

BOBR rakes. Simhadri is under advance payment scheme and the program for Simhadri

being submitted by NTPC was in the range of 6-7 rakes. Upto 8 rakes would be ensured.

Loading of 8 rakes/day for Simhadri can be done, provided adequate availability of coal

in sidings is ensured by coal companies.

NTPC-Kudgi

NTPC Kudgi requested Railways to supply 2 rakes/day from SCCL. Though the indent

has been raised supply was not taking place. SCCL / Railways stated that as per NTPC‟s


request the rakes were being diverted to Sholapur and Mouda. SCCL stated that Kudgi

was Bridge Linkage customer and 2 rakes/day would be ensured.

APGENCO

APGENCO informed that at Dr. NTTPS (Vijayawada TPS) (for the period April – May

2018), 177 rakes were supplied against 244 sanctioned rakes for raw coal and 26 rakes

were supplied against 66 sanctioned rakes for washed coal. At Rayalaseema 42 rakes

were supplied against 72 sanctioned rakes for raw coal. Around 63% supply was

effective with respect to sanctioned rakes. Railway Board (vide letter dated 09.02.2018)

had committed existing linkages through ARR. It was informed that with the

augmentation of BOXN rakes, the rake availability would improve in East Coast

Railway and help in higher materialization of ARR from Talcher in the coming months.

Requirement was of 3.2 rakes/day (2 from BBMT siding) for Dr. NTTPS (Vijayawada

TPS), 1.33 rakes/day for Rayalaseema TPP and 2 rakes/day for Rayalaseema Stage-IV.

Railways assured that materialization would increase to 80 to 90 % which was achieved

earlier in the coming months. In August 2018, the raw coal movement was already more

than 100%. For washed coal for some period the Washery was closed due to some

infrastructure additions but now the coal supply have resumed. Last month, the washed

coal supply was around 90%. Kondapalli (Vijayawada) has added advantage that they

can unload BOBR rakes. At BBMT siding 2 -3 rakes/day were being loaded.

On the request of MCL, APGENCO had requested for transfer of raw coal to some other

Washery also. More number of BOXN wagons was required as at RyTPP the unloading

facility for BOBR wagons was not there.

Railways stated that the complete requirement of washed coal could not be met only

from Spectrum Washery due to capacity constraints in the layout of the siding and hence

movement should be planned for other washery sidings also. Railways assured of higher

availability of rakes for Kondapalli as Kondapalli was good releasing point for

Railways. More number of BOXN rakes had been inducted for movement of coal for

Western and Northern Sectors but slowly the availability to Southern Sector would

improve since loading of BOXN wagons from CCL and BCCL has gone down.

KPCL

KPCL informed that 18 rakes per day were required for FY 2018-19. Additionally, 2 to

3 rakes per day were required for fly ash movement. Railways to ensure valid rakes

availability for movement through ARR. Percentage realization of rakes with reference

to 60 % of FSA quantity was only 70. 61% (for 2017-18). KPCL was also programming

movement of coal through RSR mode. For April 2018, Railways had provided only 21

rakes against requirement of 34 rakes. Less coal was being received at Raichur and

Bellary through ARR mode from MCL and it was around 25 % from WCL. Through

RSR mode the supply was being met. The supply issues were being taken up with CIL


and CEA (criteria of critical / super critical was affecting them to buildup the coal

stock).

Railways informed that due to the reason cited above the supply via ARR was less but

there was 90-95% materialization on RSR. Because of ARR/RSR options, the supply

from MCL was satisfactory while the supply from WCL was badly affected since last

two months due to less coal on account of rains. For the month of July 2018 the

materialization was around 105 % (100% ARR and 106% RSR).

Railways requested KPCL to furnish the source-wise breakup of 18 rakes/day. It was

informed that KPCL gets significant portion from SCCL. KPCL was requested to

furnish the details of fly ash movement and the type of wagons required, whether

BCCW (special wagon for fly ash) or BOXN.

TANGEDCO

It was noted that coal stock at North Chennai was for one day only (CEA report dated

09.08.2018).

Railways informed that overall supply to TANGEDCO stations was more than trigger

level. Further, as per CEA‟s criteria, North Chennai has not been categorized under

critical/super critical.

TANGEDCO stated that not a single rake had been moved from Ib to Mettur through

ARR though earlier 28 rakes and later 6 rakes had been supplied.

Railways informed that the movement of BOXN rakes to Western and Northern Sector

had affected the rake movement through ARR to Southern Sector.

NTECL

NTECL informed that realization was only around 72-75% and that also at 85% PLF.

Coal movement from Talcher to Paradip Port was quite less than the requirement of 3

rakes/day. Further, there were some issues in coal movement from Ib to Paradip and

Damra and the realization is poor. NTECL was requesting around 25 rakes to Damra

which was not being allocated.

Railways informed that there were no issues for movement between Talcher to Paradip

Port and the allocation would be optimized. As the plant was not featuring in the critical

list, the allocation of rakes could have reduced. Once the consumption increases, rake

allocation would automatically enhance. Railways stated that as per the records 100%

realization was there on Ib to Damra sector based on the submitted program. However,

the issue would be looked into.

NTECL requested Railways to ensure 1 rake/day from SCCL though the indent has been

raised. SCCL stated that the coal supply was under MOU (till now 17 rakes have been

supplied) but due to rains the loading was affected. Now the supply would be improved.


TSGENCO

SCCL informed that TSGENCO was commissioning 800 MW unit and 2 rakes/day were

being supplied to them, as it was under FSA.

MCL

In the 33rd

SRPC meeting, MCL had raised issues on availability of BOXN rakes for

maximizing long distance linkages, congestion in ECO railways (going to Paradip &

through Sambalpur – Titlagarh route) and BOB rakes to be allowed over long distances

for plants such as Simhadri ( having unloading facilities).

Railways informed that these issues are being discussed and resolved on day-to-day

basis with MCL.

MCL informed that these issues are being taken up in the sub-group meeting on daily

basis.

12.12 Unloading facility issues

SCCL pointed out that some of the stations don‟t have facility of unloading BOBR rakes

which needs to be developed to provide flexibility in supply of rakes. This affects coal

supply to Muddanur, Raichur, Bellary, Kudgi etc. Major coal plants should have

multiple type of unloading facility.

12.13 Issues on CEA’s methodology for monitoring coal stock

NTECL

NTECL informed that they were getting coal through RS mode and it was taking more

than 10 days. As per CEA‟s criteria if the coal is available for more than 7 days it is not

categorized under „Critical‟. In case of increased generation level, movement from

„Critical‟ to „Super Critical‟ is very fast. Therefore for RS mode, criticality should be

fixed at least 10 days.

NTPL

NTPL stated that the same issue has been raised by NTPL and the time lines for the

movement of coal were further severe.

KPCL

KPCL stated that the CEA‟s methodology was affecting to build up coal stock.

Computing 30 days stock at 85% PLF they require 7.36 MT while the stock is 3.98 MT

(CEA website showing 27 days) at Raichur TPS. The issue had been taken up by MD,

KPCL with CEA.

TANGEDCO

Most of the power plants are under shutdown/partially running to harvest the wind

power and hence consumption of coal was around 25-30%. CEA is computing the stock


in number of days based on the past few days consumption pattern. For example for 26th

,

MCL has mentioned that Tuticorin is having coal stock of 25 days (based on running of

only one unit) but actual stock was for 5 days only. TANGEDCO is very badly affected

due to this. On the other side TANGEDCO is being requested to build up stock to 30

days (for full station capacity). CEA‟s computation methodology was not clear.

Conclusion

It was pointed out that computation methodology had been finalized by CEA in

consultation with the stake holders and is available in public domain. The stake

holders had been kept appraised on the methodology.

Member (GO&D), CEA stated that the issue would be examined, in case the same is

referred to CEA.

Chairperson, SRPC stated that since more than one state is having issue in the

calculation, the issue could be taken with CEA. All affected entities were kindly

suggested to provide detailed inputs / reports for further taking up with CEA.

13 STATUS OF DC/GENERATION IN ISGS

13.1 Issue regarding low DC/Generation at NLC TS-II Expansion and NTECL had been

deliberated in earlier Meetings of SRPC. Level of generation of some ISG stations is given

below:


MS, SRPC had informed that the loss in DC wrt normative was 956/272/356 MW

during Nov 2017/Dec 2017/Jan 2018 respectively. While scheduling right is with

beneficiary, DC being the sole prerogative of generator should not be less.

NLC had informed that some modification works through OEM had been planned and

full availability was expected during the first quarter of 2018-19.

NTPC & NLC had requested for maximization of consent for trading.

Subsequently it has been noted that NTECL unit-III which was out since 06.06.2017 had

come back on bars on 27.02.2018.


Loss in DC was 167/151/117/292/156/394 MW during Feb 2018/March 2018/April

2018/ May 2018/ June 2018/July 2018.

NLC had informed that major modification had been carried out in Unit II of TS II

Expn and unit brought back in June 2018 .Unit I would be brought back by 15th

August

2018 and after that, above 90 % DC was expected.

Station Feb-18 Mar-18 Apr-18 May-18 June-18 July-218

NTECL,

Vallur

DC % 67.19 72.63 98.18 80.23 64.43 73.90

PLF (on Actual)

%

56.43 62.88 85.91 97.57 48.87 46.53

NLC TS II

Exp

DC % 44.14 31.52 25.78 30.62 16.72 45.62

PLF (on Actual) 29.51 32.43 26.34 30.97 17.26 41.91

MAPS PLF (on Actual) 51.24 51.04 50.20 49.03 50.51 48.46



14 ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY

14.1 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.

(ii) 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.

14.2 In earlier Meetings the following had been noted:

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

December,

2017 in the matter of „Automatic Generation Control (AGC) pilot project‟.

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. AP utilities as well

as SERC were required to be consulted in this regard.

14.3 A Meeting on AGC issues had been conducted at SRPC on 28th

March 2018 (MOM

available on SRPC website). The following highlights may be kindly noted:

Better Load Forecasting and RE framework (forecasting, scheduling & settlement)

would naturally result in lesser reserve requirement and needs to be pushed through

FOR.

Scheduling software for unit commitment, meeting the ramps (+)/(-), ramps of

generators, fast start up and shutdowns of generators, errors in load and RE forecast,

technical minimum, meeting peak demand, meeting minimum demand, net load,


pump operation etc is required for resource optimization and proper decision

support.

Forum opined that there was a need for a Procedure to quantify Secondary/Tertiary

Reserves. Procedure should also include a mechanism to monitor these reserves in

real time manner for replenishment of these reserves.

Sharing of these secondary/tertiary reserves, and including those available with

States, could lead to optimization of reserve requirement. However, the mechanism

of sharing and associated cost needs further analysis and discussions.

While there was lot of focus on positive reserve, during large RE ingress, negative

reserve is also required. This needs to be covered prominently in the reserve ambit.

It was strongly felt that secondary and tertiary reserves should always be available

with system operator and cannot be dynamic with URS availability (diminishing

during peak hours) or with all units are running in Technical Minimum (no negative

reserve). Whether this could be achieved through Market based reserve or through

regulatory mandatory market needs to be studied?

There needs to be a mechanism in place for sharing of secondary/tertiary reserves

available with the states. These reserves are to be made available with the system

operator.

A time bound implementation of ABT in the states is also necessary for AGC

(Secondary)/Tertiary Reserves to take off.

Forum (except NLDC/SRLDC) was of the view that Gate Closure already exists (30

minutes prior to the delivery) as per IEGC. This issue needs to be further examined.

Forum opined that proposed Bias Setting requires further review.

It was noted that in the Report on National Reference Frequency it has been

recommended that the dead band of +/-0.03 Hz (ripple factor in IEGC) may be

gradually phased out as is being done in ERCOT Texas and Europe‟. Generators

strongly opined that the dead band of +/-0.03 Hz (ripple factor in IEGC) may need to

be retained.

For SCADA veracity it was noted that it was joint responsibility of all the entities of

SRPC forum to take proactive and appropriate steps to ensure consistency in data.

The issue needed due attention it deserves as it is critical in grid operation. The

entities needed to have dedicated team with 24x7 support specifically at

SLDC/RLDC/NLDC/CTU/STU.

It was noted that the Optical Fibre Connectivity could be assessed and action plan

could be finalized by CTU/STU.

There is a need to have AGC pilot projects in all the SLDCs. It was thus

recommended that each SLDC could have a AGC standalone infrastructure with one

or two stations wired for AGC as Pilot Project. This approach would enable faster

implementation of AGC upto the state level. This would ensure hands on experience

at State Level at a faster pace along-with the development of infrastructure facility at

SLDCs.

IEGC provision that the schedules should not exceed capacity on bar less Normative

Auxiliary Consumption need to be implemented pan India for all generators- ISGS,

State generators, IPPs, MPPs etc.

The forum strongly advocated for AGC also for RE generators. There would be need


for both positive and negative reserves provision for RE also. There is need to have a

well laid down procedure including commercial settlement, which could also be a

market based mechanism.

14.4 In the OCC Meetings the following had been noted:

KPCL had informed that M/s Andritz for Varahi and M/s ABB for Sharavathy have

been identified for the AGC implementation by USAID / PRDC for which, KPCL has

given approval. This was expected to be completed by December 2018. Further, AGC

for 10 MW of Solar project at Sivasamudram was also under consideration.

Simhadri, NTPC informed that the infrastructure readiness for AGC was likely to be

in place by August 2018.

A Workshop had been conducted on 15Th

May 2018 at APSLDC by NLDC on AGC

at NP Kunta.


APTRANSCO had informed that APGENCO is willing to speed up the AGC activity

since more RE has to be integrated. Some lead by SRLDC & SRPC Secretariat would

expedite the Pilot Projects.

KSEBL had suggested to explore the possibility of obtaining funding for

implementation of AGC for utility owned generators and to create suitable market

mechanism.

NLDC had informed that States need to take action as per the Regulations/Orders.

Simhadri AGC may be in place by mid-September, for Mouda (WR), Barh (ER) &

Bongaigaon (NER) tender specification had been rolled out and tender would be floated

by end of August 2018. Detailed road map for Phase I & Phase II had been submitted to

Hon‟ble CERC. For other Pilot Projects, approval of CERC would be sought shortly.

NLDC SCADA is being upgraded with AGC software to include Stations for which

tariff is determined by the Commission and NLDC would be approaching Commission

for approval.

SRLDC had observed that as per CERC Regulation/Order, the AGC should takeoff in

the state generators also. Considering the high RE penetration in SR, TCC could

suggest on AGC pilot project implementation in each state.

NLDC had informed that stand alone AGC software was available. From existing

system tie line flow and frequency data was an input. A communication link to the

generating station was required along-with the protocol compatibility to be included in

LOA. Hardware and software was available. Licensee cost would increase with number

of units wired for AGC. The protocol between SCADA and AGC software has to be

established.

NPC had opined that stand alone system may be sufficient for all the generators and not

only for those in the Pilot Project.

As noted in Meeting held on 28.03.2018, Pilot Project on AGC was agreed to be

implemented in all the states. States could approach the State Regulators and

commence the Pilot Project.


NLDC had agreed to assist on technical aspects in the AGC implementation.

It was also agreed that a Committee with participation from State SLDCs, GENCOs,

SRLDC and NLDC would be formed to facilitate Pilot Project implementation in the

states.


15 TTC/ATC

15.1 ATC/TTC computations by SLDCs

The following had been noted in earlier Meetings:

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.

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 Yes

TS Yes Yes No No Yes Yes

KAR Yes Yes No No No Yes

TN Yes Yes Yes No Yes Yes

KER Yes Yes Yes No Yes Yes

The following had been noted in the OCC Meetings:

APSLDC had constituted a Study Group. While one DE had been posted, supporting

staff was to be posted.

SRLDC had assured of cooperation in training of the officials in this regard.

TCC deliberations

APSLDC informed that from August 2018 onwards, PSSSE base case would be

furnished.

SRPC noted the above.

15.2 Harmonization of Philosophy of Computation of Total Transfer Capability (TTC) by

POSOCO and CTU between ER-SR & WR-SR

In a Special Meeting convened by NPC on 23rd

October 2017, members had agreed for the

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

operationalization and grant of MTOA.

SRPC/TCC had requested NPC to similarly kindly finalize procedure for base case

preparation by POSOCO, in respect of STOA.

In line with the decision taken in the 32nd

TCC meeting, SRPC Secretariat had taken up the

issue of finalizing the procedure for base case preparation by POSOCO in respect of

STOA with NPC vide letter dated 05.03.2018 (Annexure-XXVI).


TCC deliberations

NPC had informed that vide letter dated 12.03.2018, NPC had taken up the issue

with all RPCs seeking opinion/views on base case preparation by POSOCO for

STOA. For LTA/MTOA base case preparation methodology, NR & NER were not

part of deliberations and thus it was felt prudent to consult all the regions.

NPC had agreed to call for a Meeting to finalize the Philosophy for the computation

of TTC for STOA by POSOCO.


15.3 TTC/ATC enhancement – Operational guidelines issued by NRCE

SRPC vide letters dated 13.11.2017 and 20.11.2017 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.

NPC vide letter dated 13.03.2018 (Annexure-XXVII) had again taken up the issue with

CTU and requested that the required details of terminal equipment be furnished. It was

observed that the same request had been conveyed to CTU vide NPC letters dated

21.11.2017, 19.12.2017 and 16.02.2018.

In the 5th

Meeting of Grid Study Committee (GSC) held on 18.06.2018, Chairperson, CEA

had observed on increasing the TTC through dynamic loading of the line, use of HTLS etc.

CTU had been kindly requested to furnish the information sought by NLDC for TTC/ATC

enhancement as per operational guideline for determination of TTC, ATC and TRM for

short term horizon (0-3 months) issued by NRCE.

TCC deliberations

NPC had informed that CTU vide letter dated 18.04.2018 had furnished the details

for all the regions. Onus was with NLDC/RLDCs to consider the equipment ratings

and revise the TTC/ATC.

CTU had confirmed that all India information had been furnished to POSOCO.

Further they were willing to sit together for additional requirement, clarification etc,

if any.

NLDC had agreed to look into the issue and enhance TTC as per the Operational

Guidelines issued by NRCE.


16 ISSUE OF PREVAILING OVER VOLTAGES IN SR GRID

16.1 Number of nodes in SR are facing high voltage problems. PGCIL had pointed out that 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.

16.2 In the operational feedback, POSOCO for the quarter (April-June 2018) had highlighted


high voltage nodes (41 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.

16.3 Details of nodes of high voltage coupled with MVAR injection during February 2018 to

June 2018 are given below:

Nodes with MVAR injection during V > 103%

AP KAR TN TS

Nellore PG Nelamangala Tiruneveli Maheshwaram

Kurnool Mysore Alamathy Hyderabad

Vijayawada Karaikudi Malkaram

Gazuwaka Pugalur Gajwel

Chittoor Mehaboobnagar

Vemagiri Khammam

Warangal

Dichipally

16.4 The issue of high voltage at 400 kV Uravakonda and 400 kV Jammalamadugu sub-stations

was taken up with APSLDC vide letter dated 03.07.2018 (Annexure-XXVIII) by SRPC. It

had been stated that KSEBL had informed that RE generators are not being penalized

(charges suspended) on injection or absorption of MVAR in case the same is as per SLDC

instructions. It was suggested to consider similar philosophy in AP system to contain the

high voltage scenario. It was also proposed to constitute a group of officers from SRLDC,

SRPC and states who will visit major RE notes facing high voltage and suggest any

improvement in the Operating Procedure.

16.5 PGCIL vide letter dated 26.07.2018 (Annexure-XXIX) had expressed concern on over

voltages above 430 kV in the system observed at Pavagada, Tumkur, Mysore, Hassan,

Hiriyur, Kolar, Karaikudi, Dharmapuri, Salem and Thiruvalam stations. Providing VAR

compensation/STATCOM at few of these stations shall be explored

Further, PGCIL had expressed concern on frequent hand tripping of 765kV Kurnool –

Thiruvalam lines and 765 kV lines connected to Nizamabad and Maheswaram GIS stations.

This issue was deliberated in 33rd

SRPC meeting and it was decided to minimize the number

of switching operations. Same may be discussed as the reduction in frequency of switching

on daily basis is awaited.


SRLDC had presented the issues in this regard (refer Operational Feedback available at

NLDC website). Commissioning of the reactors and STATCOM needed to be expedited.

SRLDC informed that the number of lines being taken out to curtail Over voltages


increases with RE ingress and it had gone up from 10 lines/day average to around 20

lines/day in June.

APTRANSCO had informed that Jammalmadugu reactor would come up by December

2018. After tying Vemagiri (PG) & Vemagiri (AP) the voltages have gone up.

APTRANSCO, KPTCL, TANTRANSCO and TSTRANSCO had agreed to look into

this issue and come out with short term and long term measures to address the same.

SR-II had stated that in some instances when there is a known trend of increase in

voltage, SRLDC is directing to open the lines at voltages around 435 kV which needs to

be avoided. Manual tripping above 430 kV should be avoided. SR-II had requested that

lines may be manually tripped between voltages of 420 - 425 kV to reduce stress on the

equipment.

SRLDC had assured that the lines would be taken out proactively considering N-1

reliability. Further, pro-active action would be considered in case of known trends of

increase in voltages and lines would be opened at voltages less than 430 kV. In case of

double circuit, one line would be taken out on sustained basis (7 days) to avoid frequent

switching operations.


17 ISSUES IN RESPECT OF NPCIL

The following are the issues in respect of NPCIL stations:

17.1 Balance dues from Beneficiaries

Issue of outstanding dues to NPCIL of Southern Region beneficiaries had been discussed in

the 32nd

/33rd

Meeting of SRPC. All the beneficiary states had assured of early settlement of

the dues. The issue was regularly followed up by NPCIL stations and MS, SRPC and it was

further discussed in the 38th

CCM. Director (F), NPCIL vide letter dated 31.05.2018

(Annexure-XXX) had expressed concern on significant dues. The outstanding dues to

NPCIL as furnished by NPCIL vide letter dated 26.07.2018 (Annexure-XXXI) are as

follows:

(Figures in Crores)

Sl.

No.

Entity

MAPS

KGS

KKNPP

Bill

Amount

Delayed

payment

charges

1 TNEB 160+78 185+123 157 138

2 HESCOM (Karnataka) 1 205+78 168 25

3 Telangana 6 158+2 0 2

4 GESCOM (Karnataka) 2 65+6 65 4

5 CESCORP (Karnataka) 3 46+4 37 3

6 APTRANSCO 7 59+11 1 1

7 PED (Puducherry) 3 13+0 21 2

8 BESCOM (Karnataka) 1 3

9 KSEBL 7

Further the shortfall in LC amount was also furnished.

TCC deliberations


NPCIL had expressed concern on dues to the extent of about Rs 1,848 crores (as on

30.06.2018) from SR beneficiaries. Considerable cash flow constraints were being

faced.

SRPC deliberations

SD, KKNPP stressed upon the timely payment of dues by the beneficiaries since it

puts lot of strain on resources and the cash flow is affected severely. He thanked TN

for clearing significant amount of dues in the last month. Dues as on date were also

quite significant and lot of payment was due from Karnataka Discoms. He stated that

NPCIL was a government organization and the fund mobilization was difficult.

PCKL stated that they had held a meeting with Discoms in this regard and a procedure

for timely clearance of the bills has been formulated for implementation.

All beneficiaries were requested to kindly clear the dues and increase the LC amounts

at an early date.

17.2 Part load operation/Reserve shutdown/frequent changes in revival of KKNPP units

In the 32nd

TCC Meeting, it was noted that with higher RE penetration, NPCIL units

need to offer some flexibility (seasonal, part load etc) which was need of the hour.

SR constituents had suggested that only one unit of KKNPP could be in service during

July to September each year and refueling need to be planned accordingly.

SR constituents had pointed out that during peak demand months (Feb to Apr) both the

units at KKNPP need to be in service. The 1000 MW size of KKNPP units has

significant impact on the LGB and even affects the power market price also.

Frequent changes in revival were completely distorting the purchase planning and their

LGB of the control area. TN as a major beneficiary was impacted by around 550 MW

for any delay in revival of the unit.

To achieve the above requirements part load operation / reserve shutdown needed to be

contemplated by NPCIL.

Chairperson, SRPC vide letter dated 11.04.2018 (Annexure-XXXII) had taken up the

pertinent issues with CMD, NPCIL.

TANTRANSCO vide letter dated 11.06.2018 (Annexure-XXXIII) had taken up the

issues like bringing back the unit II in service till July end ie till availing shutdown of

Unit I, availing AOH of Unit I once Unit II is brought into service, consider either only

one unit in service till September 2018 end and both the units to be available from

October 2018.

Director (F), NPCIL vide letter dated 31.05.2018 (refer Annexure-XXX) had requested

that the beneficiaries may surrender surplus power on long term basis so that MoP may

be approached by NPCIL for allocation of the same to other beneficiaries in need of the

same. Further, it had been pointed out that in view of the defaults in payments of more

than 6 months and in most cases 4 to 5 months, it was requested to reduce the

entitlement of these beneficiaries from Kudankulam power of NPCIL to the extent of

surplus power available even if it is more than 15% which will enable NPCIL to sale it

to others for cash and the serve the purpose of both the ends, energy consumers and

producers, NPCIL.


TCC deliberations

Unit 1 had been taken out on 1.08.2108 and would come back on 05.11.2018. Unit 2 is

under forced outage since 02.08.2018 and is likely to come back on 01.10.2018.

With reference to revival of Unit 2, OCC had concluded that injection upto 1,000 MW

(corresponding to one unit) could be maintained during the short period of around 10

days since huge RE was being injected into the grid, hydro generation was significant

and number of units had been taken under NLD/RSD (4,000 MW under RSD &

13,000 MW under various outages). Daily flexibility had been categorically refused

by KKNPP, on technical considerations. However, OCC was of the opinion that at

least seasonal flexibility could be offered by the NPCIL units. SRPC letter dated

18.07.2018 in this regard is enclosed at Annexure-XXXIV. KNNPP letters dated

18.07.2018; 19.07.2018 & 20.07.2018 addressed to SRPC/SRLDC are enclosed at

Annexure-XXXV.

NPCIL had pointed out that discussion in OCC forum was not in line with nuclear

power policy. NPCIL units are of base load nature and are not governed by ABT. For

part load/RSD there is no compensation mechanism available and it is direct loss to

the Company. Clause 3.2 of PPA (15 years) clearly states that the beneficiary shall at

all times endeavor to take all the power, which the power plant is in a position to send

out. Frequency cannot be predicted by OCC two months in advance. Further, OCC

discussions were not communicated to appropriate level at Stations/HQ and thus

proper reply was not communicated by NPCIL.

It was pointed out that PPA also mentions that, „However in the event of over

frequency conditions, the SRLDC would regulate their generation/drawal as per the

SRPC/SRLDC guidelines to maintain frequency.‟ Inputs to decide high frequency

conditions can be decided by OCC.

SRLDC had stated that excess injection could lead to undesired U/D and overall grid

conditions have to be considered. KKNPP being part of grid needs to comply with

provision of EA/ Grid Code. Bypassing operational requirements citing PPA clauses

and commercial grounds is against the grid operation principles.

PCKL had stated that at times, generation from NPCIL units is not as per requirement

of the states. As per EA, SRLDC & SLDC are empowered to give suitable directions

in the interest of security of the grid. Grid security, operational efficiency etc has to be

ensured by RLDCs as per Grid Code. In single part tariff, full charges would be

recoverable at some defined PLF.

KSEBL had stated that CMD KSEBL had directed to communicate that all Discoms

are under financial crunch while NPCIL is a profitable organization and these are

factors to be considered when decisions are taken on commercial principles. Request

had been made to restrict injection upto 1,000 MW. Reactor should have been

powered accordingly. KSEBL vide letter dated 21.07.2018 (Annexure-XXXVI) had

taken up the issue with SD, KKNPP with a copy to CMD & Director (O) NPCIL, for

which no prompt reply was given and some reply had been received, couple of days

back. On one part tariff issue, some compensation can be worked out for RSD of the

unit, but for that NPCIL should have come forward. KSEBL vide letter dated

03.08.2018 (Annexure-XXXVII) had suggested to revise the REA indicating energy


injected without consent by NPCIL, separately. This has gone against the principle of

most economic operation of the grid as envisaged in the Act. As per provisions of

PPA, KKNPP should be ready to reduce the generation in case frequency is high.

TANTRANSCO had stated that 6,000 MW of RE is injected into grid coupled with

around 1,000 MW of KKNPP power (fixed with no flexibility) making it a difficult

task for the system operator to maintain LGB. Part load operation should also be

considered by NPCIL units.

TSTRANSCO had stated commercial issues as suggested by Kerala could be worked

upon. When grid is under stress, generators also need to cooperate.

After discussions, it was agreed that PPA may need to be revisited and

TANTRANSCO would kindly take the lead in this regard. Flexibility, two part

tariff, compensation for backing down etc were issues to be discussed.

It was agreed that the injection beyond 1,000 MW from 21st July 2018 to 2

nd August

2018 would be shown separately in the REA.

KSEBL had stated that the payments for this additional injection would not be made

by them. KPTCL also had stated that they would take appropriate call in this regard.

SRLDC had stated that allocating some quantum of power to other states could be

considered which may be useful in absorbing KKNPP power. Further it could come

under RRAS. It was pointed out that presently, nuclear generating stations are not in

the scheduling ambit.

It was noted that flexibility could be considered in future PPAs of NPCIL units.

NPCIL had reiterated that there was no compensation for backing down/reserve shut

down and as per PPA entire power is required to be absorbed by beneficiaries. The

units are base load stations and daily flexibility cannot be provided. On daily basis,

update of revival of unit is reviewed by CMD, NPCIL and Chairman, Atomic Energy

Commission.

It was noted that there was provision for curtailing the generation as per RLDC

directions in case of high frequency. It was suggested that the same could be

implemented by SRLDC as per any communication received from the beneficiaries.

However NPCIL stated that any directions in this regard would need to be adequately

justified by SRLDC.

Beneficiaries had strongly recommended that the shutdown of NPCIL units of

SR should be availed only during June to December each year.

It was agreed that Chairperson SRPC would be requested to take up the pertinent

issues with MoP.

SRPC deliberations

SD, KKNPP stated that suggestion of the states that nuclear generating stations should

adjust its generation keeping in mind generation from renewable energy sources is a

challenge to the basic design concept of nuclear power station itself. Even though

there may be deliberations but the same may not be feasible. PPAs are signed for 15

years and revisiting of the PPAs may not be practical. As far as scheduling of outages


is concerned, it is well known that the KKNPP units require refueling after every 300

days of full load operation. As soon as 300 days of full load operation is over,

operators cannot extend the running of the unit even for one day. There is a difference

between PLWR and PHWR technologies. The reactors at MAPS and Kaiga GS have

online refueling possibilities and in these stations, little bit of rescheduling is possible.

It was agreed that there had been more number of unscheduled outages. Unit-1 was

made commercial in the year 2014 and year after year the performance is improving.

This reactor had undergone two refueling cycles and performance of the unit after

second refueling (capacity factor) was about 92.5%. Unit-II has undergone only one

refueling cycle and they were hopeful that after sorting out the teething problems the

performance of Unit-II would be at par with Unit-I. Before PPAs were signed, the

same had been deliberated at length in MoP, wherein it was noted that nuclear stations

were expected to be base load stations. KKNPP installed capacity is hardly 2% of the

installed capacity in SR and not absorbing the power cannot be appreciated.

Sometimes NPCIL also suffer losses when the payments are not received and the

moneys have to be borrowed from banks in addition to the expenditure incurred on

interest. NPCIL has also reached a stage where further money cannot be borrowed

since limit has been reached. These views from NPCIL should also be taken into

account and constituents should not expect some things which are impractical due to

the limitations in the design not only for NPCIL but for nuclear reactors all over the

world. World over nuclear stations are operating as base load stations. Improving the

performance and reliability was NPCIL‟s responsibility and shortly they would

overcome the constraints. For KKNPP units the refueling cycle cannot be altered as

per the requirement of the beneficiaries. He hoped that Electricity Boards would

appreciate and understand these concerns.

It was pointed out as NPCIL was a commercial organization states were also running

under commercial principles. Any deviation beyond limits attracts penalties. If

underdrawal increases there are no payments receivable and beyond certain frequency

even penal rates are applicable. In this case, the beneficiaries had only requested only

some minimum response from NPCIL (to avoid injection beyond 1,000 MW) since

there was underdrawal and high frequency conditions were prevailing.

SD, KKNPP stated that it was in the interest of nuclear station that it operates at stable

power level. Request from states is varying and when KKNPP units were coming up

the state has requested for higher share. Concerns of the state electricity board are well

understood and appreciated, however nuclear stations are to be operated within certain

limitations. Some adjustment in power level in the long run (not on a daily basis) is

something new and needs to be discussed at length. In case some compensation to

NPCIL could be worked out, it can be thought of. It is in the interest of states to

absorb nuclear power since RE energy was variable.

It was pointed out that earlier there were power shortages but now states have surplus

power. Merit order operation has also kicked in and RSD procedure is in place,

Technical minimum has been introduced and the operating philosophy has undergone

sea change. KSEBL has suggested for some commercial mechanism and NPCIL also

needs to come forward in this regard.

Chairperson, SRPC observed that it is a commercial situation and this is the reason

why some generators are being backed down. Technical difficulties of NPCIL units


are well appreciated but NPCIL could consider the request of the beneficiaries

regarding the outage plans. The outages of the units are to be planned between June to

December for SR as in monsoon SR demand is lean. All electricity boards in the

country are suggesting that the nuclear stations should be operational during summer

and winter. Therefore, there is a window to complete the maintenance for all the

NPCIL units in the country.

It was concluded that Kaiga GS and MAPS units shutdown should be planned

between June to December, while KKNPP units shutdown would be endeavored

between June to December.

PCKL pointed out that there was a need for change in the Tariff structure for nuclear

stations. In the new concept paper three part tariff was being considered for thermal

stations. In the changed scenario balancing part has to be managed both at generation

and consumer ends.

As suggested by TCC, it was agreed that PPA may need to be revisited and

TANTRANSCO would kindly take the lead in this regard. Flexibility, two part

tariff, compensation for backing down etc were issues to be discussed.

Beneficiaries strongly recommended that the shutdown of NPCIL units of SR

should be availed only during June to December each year.

Chairperson, SRPC stated that considering all these factors issues could also be taken

up with MoP justifying the requirements of the beneficiaries.

17.3 BSD of KGS units

Kaiga 1 & 2 would inform the extended dates for BSD of Unit 1well in advance to

OCC/SLDC KPTCL for the states to plan their LGB in an economic and secure manner.

Shutdown of unit 1 would not be allowed during Jan to April 2019.

On similar lines Kaiga GS would consider request of OCC for postponement of BSD

scheduled during Jan to April, for any of the units in future.

All units would be planned for BSD during June to December only each year.

17.4 Black Start Mock Drill at Kaiga GS and MAPS

In the Meeting held on 22.06.2018, KGS had informed that Black Start Mock Drill

would be taken up during BSD of the unit-I on similar lines to KKNPP.

MAPS Black Start Mock Drill is to be carried out.

17.5 PSS tuning / SRT

In the Meeting held on 22.06.2018, Kaiga GS agreed for PSS Tuning of unit during BSD

of Unit 1 & III respectively.

MAPS Unit –II PSS tuning/SRT is to be completed.

17.6 MVAR interchange by Kaiga GS units (meeting held on 22.06.2018)

Kaiga GS units 1 & 2 would start absorbing as per Capability Curve above 225 kV and

there would be no injection at voltages in the range 220-225 kV.

Kaiga GS/NPCIL would take all steps to ensure commissioning of first 125 MVAR by

December 2019. Kaiga GS/NPCIL would also initiate the tendering activities of second

125 MVAR reactor and same needed to be confirmed with the detailed commissioning

plan in the 33rd

TCC/34th

SRPC scheduled in August 2018.


During testing activities of generator 3 & 4 with respect to MVAR absorption, Kaiga GS

would involve SRPC/SRLDC.

Kaiga GS would endeavor to support the grid within the mandated provisions of

IEGC/CEA & CERC Regulations.

17.7 2x125 MVAR Reactor commissioning at Kaiga GS (meeting held on 22.06.2018)

In Kaiga GS/NPCIL informed that technical bid had been opened for the first 125

MVAR reactor on 20.06.2018. The reactor was planned to be commissioned by

December 2019.

Kaiga GS/NPCIL assured that bidding activities for second 125 MVAR reactor would

be initiated.

As discussed in the Special Meeting held 22.06.2018 held at Kaiga GS, Chairperson,

SRPC vide letter dated 26.06.2018 (Annexure-XXXVIII) had taken up the issue with

CMD, NPCIL.

CMD, NPCIL vide letter dated 02.08.2018 (Annexure-XXXIX) had replied to

Chairperson, SRPC‟s letter and had stated that tender had already been floated for

supply and commissioning of one 125 MVAR reactor for which technical bids had been

opened. Engineering details and estimates for replacement of existing 63 MVAR reactor

are being worked out and it would be replaced with 125 MVAR reactor soon after

commissioning of first reactor. All efforts were being made to expedite early

commissioning of these reactors.

17.8 Other issues as noted in the Meeting held on 22.06.2018 and other Meetings

Kaiga GS/NPCIL agreed for providing Differential and REF protection in different

relays in ICT-1&2. This would be complied by December 2018 by procuring additional

relays.

LBB time setting for lines is 0.25 sec and for ICTs - 0.2 sec. Kaiga GS informed that the

settings have been reviewed and it has been decided to keep settings as 200 msec for all.

Approval letter from HQ has been received and it would be completed during Bus

Shutdown at the time of BSD of Unit 1.

KGS agreed to disable sending of DT to remote ends upon 86 X operations for any line

protection operation at its 400 kV KGS within one month.

KGS agreed to ensure time-synchronization of all protection relays with GPS in their

400 kV switchyard by December 2018.

KGS agreed to use stipulated formats for furnishing FIR and TR.

KGS agreed to include line backup protections in Main I & Main II within 2 months,

and configure DR‟s & EL‟s of Main I & II for recording all mandated protections.

Kaiga GS would extend support for insulator replacement in Kaiga complex. Once

concurrence is received from Kaiga GS by SR-II, the works would be completed within

3-4 months as new work order had to be placed.

SRPC/SRLDC had pointed out that as User it was responsibility of Kaiga GS to ensure

data availability to SRLDC. RTU has been handed over to Kaiga GS and Kaiga GS

needed to have a backup arrangement for RTU maintenance. It was agreed that Kaiga

GS would formally take up the RTU related issues with SR-II, PGCIL with a copy to

SRLDC/SRPC. SRLDC would try to facilitate the works through SR-II, however the

onus of SCADA compliance rested with Kaiga GS.


Kaiga GS agreed to extend the digital status under URTDSM within a month.

KKNPP had informed that the rectification for the other reactor would be taken up in

April/May 2018 and expected to be completed by December 2018.

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 September

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.

SRPC noted the above and suggested NPCIL to close the pending issues in a time bound

manner.

18 UPCOMING TRANSMISSION SYSTEM

18.1 42nd

Standing Committee on PSPSR

18.1.1 Minutes of Meeting of 42nd

Meeting of Standing Committee on Power System Planning

in SR (meeting held on 27.04.2018) had been issued on 15th

June 2018 (available on CEA

web site).


18.1.2 Joint System Study Meeting of SR was conducted on 10th

& 11th

May 2018 at SRPC,

Bengaluru. The MoM is enclosed as Annexure-XL. The following issues were

discussed:-

Evacuation of power from RE sources in Southern Region (proposed Wind Energy

Zone by MNRE )

Intra-state transmission projects proposed for Green Energy Corridor Phase-II in

Karnataka.

High flow on 400 kV KKNPP – Tirunelveli D/C line after commissioning of 400 kV

KKNPP-Tuticorin PS D/C line.

Providing additional feed to 3 x 500 MVA, 400/220 kV Sub-station at Mylasandra

(Electronic City) and establishment of 2 x 500 MVA, 400/220 kV S/S at

Dommasandra, Bengaluru.


18.2 Operationalization of LTA

In Petition No. 12/SM/2017 along-with I.A. No. 54/2017, in the ROP for date of hearing

15.05.2018 (Annexure-XLI) it was noted, „….the representative of CTU further

submitted that there are certain regulatory issues in operationalization of LTA as under:

(a)Non-opening of LC ………..(b)Relinquishment en-masse (specially on HCPTC

corridor) ……….(c)Abandonment of Generation Project / Adverse Progress…. After

hearing the representative of CTU, the commission reserved orders in the petition.‟

SRPC noted that the above could be discussed in the Meeting planned with CTU & SR

constituents to discuss sharing of transmission charges/ operationalization of LTA etc.

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

32nd TCC: 800 kV December 2018. 320 kV: September 2019.

CEA (May 2018): Work held up in Tamil Nadu due to severe ROW -Critical.

Huge forest involvement (432 Ha.) in WR portion incl. Wildlife Sanctuary

clearance. Critical.

320 kV: Feb 2020 - Progress affected due to severe ROW problem in Tamil Nadu

area.

33rd TCC: Progress in Tamil Nadu very slow due to RoW issues. Issue taken

up with State administration and project is under review by PMO under

PRAGATI.

b) 765 kV Angul - Srikakulam PS D/C

Corridor

Main corridor commissioned. Other

associated elements by July 2018.

33rd TCC: PGCIL informed that Garividi- Srikakulam PS Trial Operation was

over.

c) Additional inter-Regional AC link for

import to Southern Region, i.e., Warora -

Warangal - Hyderabad- Kurnool 765 kV

link

TBCB, PFCCL- BPC Transmission Licensee : Warora-

Kurnool Transmission Limited

(WKTL)

32nd TCC: There was a Meeting held to consider preponing 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.

CEA (May 2018): Nov 2019.

d) System strengthening within SR for

transmitting power beyond Vemagiri TBCB- RECTPCL-BPC Project has been awarded to PGCIL

under TBCB, and was expected by

April 2019.

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.

POSOCO’s Operational feedback for the quarter April to June 2018

The import capability of Southern Region can only be increased after the

constraint on ICTs at Vemagiri (PG) is relieved. The commissioning of following

765 kV outlets at Vemagiri(PG) need to be expedited in order to relieve the

constraint on Vemagiri ICTs:

a) 765 kV Vemagiri – Chilkaluripeta D/C

b) 765 kV Chilkaluripeta – Cuddapah D/C

c) 400 kV Chilkaluripeta – Narasaraopet D/C

d) 400 kV Cuddapah – Hindupur D/C

e) 400 kV Cuddapah – Madhugiri

18.3.2 Updated detailed status of upcoming inter regional scheme is furnished at Annexure-

XLII.

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:


18.5 Status of important Transmission Systems

18.5.1 Updated status of associated links is furnished below please:

Transmission Elements

1 765 kV S/C Salem PS (Dharmapuri) - Madhugiri P S line (initially charged at

400 kV) ; 243.23 ckm; PGCIL

CEA (May 2018): Sep 2018, Severe ROW in Karnataka. Obstruction is being

removed progressively with the help of Police protection.

Covered under PRAGATI.

33rd

TCC: Fdn & Erec. Completed; Strg: 233/243 kM, Expected completion:

Sept’18

2 Salem New – Madhugiri 765 kV S/C line; 219 ckm ; (PNMTCL) (A subsidiary of

PGCIL)

CEA (May 2018): Sep 2018; Severe RoW issues being faced in Karnataka, issue

highlighted to PMO level.

33rd

TCC: Fdn: 573/575; Erec: 573/575; Strg.: 188/219 kM, Expected

completion: Sept’18

Sl.

No

Name of Transmission Element

1 400 kV Tumkur-Yelahanka D/C line ; PGCIL (132 Ckm)

CEA (May 2018): Dec 2018; Severe ROW in Karnataka. Balance work re-awarded

in Dec'17. Work under progress.

33rd

TCC : Fdn: 149/178 Erec: 133/178 Strg :10/66 kM, Expected completion:

Dec’18

2 400 kV Nelamangala-Hoody LILO at kV Yelahanka ; PGCIL (20 Ckm)

CEA (May 2018): Charged on 22.03.2018 and COD from 01.04.2018

3 220 kV Tumkur – Antharasana Halli D/C ;KPTCL; LOA placed on 18.03.15 with

18 months completion schedule

Special Meeting (09.07.2018) : KIADB has to procure and hand over the land.

33rd

TCC: Partly commissioned on 12.01.2018. 7 Locations pending. KIADB to

acquire land and hand it over KPTCL.

4 220 kV Tumkur (400 kV) S/S – 220 kV Tumkur S/S D/C; KPTCL; LOA placed

on 18.03.15 with 18 months completion schedule

Special Meeting (09.07.2018): KIADB has to procure and hand over the land.

33rd

TCC: 202/209 stub concreted, 202/209 towers erected, 83.6/88.962 CKms

stringing completed. 7 Locations pending. KIADB to acquire land and hand it

over KPTCL.

5 220 kV Yelahanka (400/220 kV) S/S- 220 kV Yelahanka S/S D/C Cable;

KPTCL (11.75 Ckm)

Special Meeting (09.07.2018): End of August 2018.

33rd

TCC: 17/17 sections (5.9/5.9 km) cable laying completed. 14/16 Cable jointing

work completed. Completion by 20th

August 2018.


3 Transmission evacuation system for HNPCL (1,040 MW) Power Plant

APTRANSCO ; 400 kV TM D/C Kamavarapukota – Vemagiri; 185 ckm

31st TCC: Alternate options being explored, would be taken up with the Standing

Committee.

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

MW in Phase-I) of NTPC Limited

KPTCL : 220 kV D/C line to Vajramatti: 32nd

TCC: 209/267 stub concreted,

141/267 towers erected, 2.292/158.84 CKms stringing completed.

220 kV D/C line to Basavana Bagewadi: 32nd

TCC: Commissioned.

220 kV D/C line to Bijapur:

5

Transmission System for evacuation of power from Singareni Collieries

Generating Project (2 x 600 MW)

TSTRANSCO : STPP, Jaipur – Jagityal; 139 ckm ; 33rd

TCC : August 2018

TSTRANSCO : Jagityal – Nirmal; 148 ckm; 33rd

TCC : August 2018

33rd

TCC: Sub-station is charged on 07.07.2018 with 2 x 315 MVA PTRs. 3rd

PTR is programmed for charging in August'18.

400/11 kV Sundilla LI SS is charged on 18.07.2018 by making LILO of ckt-I of

400 kV STPP,Jaipur - Nirmal QMDC line

STPP-Sundilla Feeder Bay-1 is charged on 18.07.2018 and STPP-Sundilla

Feeder Bay-2 is programmed for charging in August'2018.

6 Damaracherla TPP Evacuation

TSTRANSCO: 400 kV Damacherla TPP – Choutuppal D/C : Sep 2018, 400 kV

Damacherla TPP – Dindi D/C : Sep 2018, 400 kV Damaracherla TPP – Jangaon

D/C : Sep 2018, 400 kV Damaracherla TPP – Maheswaram (TS) D/C : Sep 2018

33rd

TCC: TSTRANSCO have acquired the land acquisition for construction of

400/220/132 kV Choutuppal SS and the survey works of connected 400 kV lines

are under process.

7 Bhadradri TPP (Manuguru) (4x270 MW), TSGENCO

TSTRANSCO: 400 kV Julurupadu SS - Manuguru TPP D/C: 2018-19 (33rd

TCC:

All foundation works completed. Erection and stringing at 3 Nos. locations is

held up due to severe ROW issues).

400 kV Julurupadu (QM) - Suryapet S/S D/C : 2018-19, Julurupadu S/S 2x 315

MVA : Bus I and Bus II charged on 23.12.2017, 33rd

TCC : PTRs are ready for

charging.

8 Kothagudem TPS St-VII (1x800), TSGENCO

TSTRANSCO: 400 kV D/C Julurupadu - KTPS (Stage-VII): 33rd

TCC: charged on

19.05.2018.

400 kV Julurupadu – Jangaon D/C : 33rd

TCC : 69/175 Kms stringing completed

and programmed for charging in Nov'2018

Jangaon SS: 33rd

TCC : Feb 2019

9 Transmission system of KPTCL for evacuation of power from Yermarus TPS

(2 x 800 MW)

KPTCL : Yermarus TPS - Bellary PS 400 kV D/C QM, 33rd

TCC: Commissioned

on 04.05.2018

Gulbarga 400/220 kV substation- 2 x 500 MVA, 33rd

TCC: DPR approved on


09.03.2018 (to be tendered), Yermarus TPS - Gulbarga 400 kV D/C line (QM), 33rd

TCC: DPR approved on 09.03.2018 (to be tendered)

400 kV SS at Chikkanayakanahalli – 2 x 500 MVA (39th

SC), CEA (May 2018):

Sep 2018, 33rd

TCC: Land identified acquisition of land under progress.

LILO of Nelamangala – Talaguppa 400 kV D/C at CN Halli, 33rd

TCC: Land

identified acquisition of land under progress.

Termination of 400 kV D/C of Hassan from Nelamangala – Talaguppa at CN Halli

400 kV, Bellary PS - C.N.Hally 400 kV D/C line QM, 33rd

TCC: The work is split

into three parts: (a) 400 kV line from BPS to Rampura Limit : Line work

completed, (b) 400 kV line from Rampura limit to Jagalur : Line work is under

progress (c) 400 kV line from Jagalur to Chikkanayakanahalli : To be tendered

De-link 400 kV S/C RTPS-BTPS-JSW-Guttur with JSW Bus

Additional JSW TPS – BPS 400 kV D/C (QM), 33rd

TCC: Commissioned.

400 kV BTPS-Guttur D/C (QM), 33rd

TCC: Estimate under preparation.

10 Transmission System for Rayalaseema TPS (600 MW)

APTRANSCO: 400/220 kV, Kalikiri S/S – 2 x 315 MVA: 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: 2018-19

11 400 kV Somanahalli- Dharmapuri PS; 244 ckm; PGCIL

CEA (May 2018): Sep 2018 - Severe ROW problem faced in Karnataka. With the

support of state Govt. ROW issues are being resolved.

33rd

TCC: Fdn: 333/336; Erec: 327/336; Strg: 106/122 kM, Expected

completion: Sept’18

12 400 kV Mangalore (UPCL) -Kasargode-Kozhikode; 33rd

TCC: NCT in its 1st

meeting had approved the scheme through TBCB.

13 400 kV Edamon-Kochi; 286 ckm; PGCIL

Being monitored under PRAGATI.

CEA (May 2018): Sep 2018 - Severe ROW problem (long pending). Problem being

addressed progressively as per latest Revised G.O. of 30.07.15 (compensation to be

done on land value, to be finalized by concerned DC with the support of State Govt.).

Works under progress. Site is getting police protection as per requirement from State

Admn. Foundation works affected due to non-availability of aggregate. Matter has

been taken up Secy. level.

33rd

TCC: Fdn: 389/447; Erec: 323/447; Strg: 60/149 kM, Expected completion:

Mar’19, Works under progress. Adverse site conditions & heavy rains affecting

progress. Works being expedited with support of state administration.

14 LILO of 230 kV Neyveli- - Bahour at Karaikal

CEA (May 2018) : NLY- Karaikal – Aug 2018

33rd

TCC: Fdn: completed; Erec: 310/317; Strg : 81/95 kM, Expected

completion: Aug’18

15 400 kV Pavagada – Hiriyur D/C line; PGCIL

CEA (May 2018): Dec 2018- Slow progress due to ROW problem.

33rd

TCC: Fdn: completed; Erec: Completed; Strg: 102/109 kM, Expected

completion: Aug’18


16 400 kV Hiriyur – Mysore line; PGCIL

CEA (May 2018) : Jan 2019 – severe ROW issues

42nd

SCPSPSR: to be expedited to relieve over loading of Nelamangala-Mysore 400

kV D/C line getting heavily loaded.

33rd


Mar’19 – Slow progress due to ROW issues

17 400 kV Pavagada – Devanahalli D/C line; (139.30 D/C and 13.20 M/C); PGCIL

32nd

TCC: December 2018

CEA (May 2018) : Jan 2019 – severe ROW issues

33rd


Mar’19 – Slow progress due to ROW issues

18 FSC at Pavagada; PGCIL

33rd

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

33rd

TCC: 2021

Ennore SEZ (NCTPS Stage-

IV) – 2 x 660 MW

33rd

TCC: 2019-20

NCTPS Stage III – 1 x 800

MW

33rd

TCC: 2019-20 41st SCPSPSR: 2019

Ennore TPS Replacement – 1

x 660 MW

33rd

TCC: 2022-23 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) March 2020 Work awarded to M/s

Hyosung Corporation,

Korea on 21.03.18

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) CEA (May 2018): June

2018

Work awarded to M/s

Transrail. Works are

under progress

765 kV North Chennai PS -

Ariyalur CEA (May 2018): Sep

2019

Work under progress.

400 kV Ennore SEZ-North

Chennai PS CEA (May 2018): Sep

2018

Tender opened on 07.06.17.

Price bid opened and

evaluation is under 400 kV Ennore SEZ- Ennore CEA (May 2018): April


to ETPS Expn 2019 process. Approval of BLTC

to recommend to place

before board.

400 kV ETPS Expn – North

Chennai PS CEA (May 2018): Sep

2018

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 Implementation of downstream network by State utilities associated with

ISTS substation of POWERGRID

Sl.

No

Name of

Substation

MVA

Capacity

220kV

Bays

Expected

Schedule of

Substation

Remarks

1 Tumkur

(Vasantnarsapur)

2 x 500 6 Commissioned Construction of downstream

T/L for 6 Nos 220 kV bays to

be expedited by KPTCL.

Deliberations in 42nd

SCPSPSR : 4 Nos 220kV downstream links i.e. Tumkur-

Anthranasahalli 220kV D/C line & Tumkur- Madhugiri-II 220kV D/C line expected by

Sep‟18. Balance 2 Nos 220 kV downstream links yet to be taken up.

33rd

TCC: Anthranasahalli 220 kV D/C line &Tumkur- Madhugiri-II 220 kV D/C

line expected by Sep’18. Balance 2 Nos 220 kV downstream links yet to be taken

up.

2 Yelahanka 2 x 500 10 Commissioned Construction of downstream

T/L for 10 Nos (6 bays under

ISTS) 220 kV bays to be

expedited by KPTCL.


SCPSPSR: 2 Nos 220 kV downstream T/L cable to Yelahanka

DG plant expected by Jun‟18. Balance 4 Nos 220 kV downstream links yet to be

planned.

3 Bidadi 2 x 500 6 Commissioned Construction of downstream




SCPSPSR: 2 Nos 220 kV downstream links i.e Bidadi –

Magadi 220 kV D/C line expected by Mar‟19. 2 Nos 220 kV downstream Link Bidadi-

Kumbalgodu expected by Mar‟20.

4 Hiriyur 2 x 315 6 Commissioned Construction of downstream




SCPSPSR: 2 Nos 220 kV downstream links i.e. Hiriyur-Hiriyur

(KPTCL) 220 kV S/C line & Hiriyur-Chitradurga 220 kV S/C line expected by

Mar‟19.

5 Hassan 2 x 315 6 Commissioned Construction of downstream




SCPSPSR: 2 Nos 220 kV downstream T/L i.e. LILO of

Hassan(KPTCL) – Nittur S/c expected by Mar‟19.

6 Kolar 2 x 500 6 Commissioned Construction of downstream




PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had requested deliberation on

the above.


18.8 Operational Feedback

18.8.1 NLDC vide letter dated 30th

April 2018 (available on NLDC website) had highlighted

following transmission constraints as part of Operational Feedback for the quarter

January– March 2018, in respect of SR:

a) Impact on grid operation due to ferro-resonance

Outage of FSC leads to power order reduction in HVDC Gazuwaka block(s) because

high power order without the series capacitive compensation at Jeypore causes low

voltage at Gazuwaka East bus.

Frequent repetition of this phenomenon may affect reliable system operation at Eastern

region and Southern region boundary, and may even cause equipment damage if the FSC

bypass scheme fails to act in case of ferroresonance.

It was necessary to carry out necessary system improvements aimed at damping the

resonant condition.

HVDC links are critical to integrated power system operation, as the operator is able to

gain flexibility in power system operation using HVDC links. It is necessary that

extensive studies are conducted in critical HVDC installations and in cases of

overcompensated AC lines to prevent any such surprises in real-time operation.

NLDC vide letter dated 09th

March 2018 with regard to frequent occurrence of

ferroresonant phenomenon involving Gazuwaka HVDC had communicated the issues to

PGCIL.

TCC deliberations

These issues had been discussed in the Meeting held on 02.04.2018. Tertiary aux

supply issue has been rectified.


SCPSPSR: 2 Nos 220 kV downstream links Kolar-Gollahalli

220kV D/C line expected by Mar‟19.

7 Karaikudi 2 x 315 4 Commissioned Construction of downstream

T/L for 1 Nos 230 kV bay to

be expedited by

TANTRANSCO


SCPSPSR: 1 Nos 230 kV downstream T/L Karaikudi –

Sembatty 220 kV S/c line expected by May‟18.

8 Hosur 3 x 315 6 Commissioned Construction of downstream


be expedited by

TANTRANSCO


SCPSPSR: 2 Nos 230 kV downstream T/L Hosur -Shoolagiri

220 kV D/C line expected by Jul‟18.

9 Kozhikode 2 × 315

+

1 x 500

4 Commissioned Construction of downstream

T/L for 1 Nos 220 kV bay to

be expedited by KSEBL


SCPSPSR: 1 Nos 220 kV downstream T/L to

Kozhikode(KSEB) expected by Mar‟19.


Short term measures (DTPCs commissioning) complied with.

Medium Term measures (STATCOM commissioning at Jeypore) complied with.

PGCIL SR I was also requested to take up implementing Long Term Measures,

viz., refurbishing of controller protection at Jeypore to detect FR and bypass FSC.


b) Frequent tripping of Talcher-Kolar Bipole

S. o. Name of

Element

Tripping Restoration Remarks

Date Time Date Time

1 Pole 1 8-Jan-18 19:06 9-Jan-18 00:54 Series Reactor in R-Phase of Pole-1

was burnt & faulty at Talcher.

2 Pole 1 9-Jan-18 07:50 9-Jan-18 09:04 Operation of Valve Cooling

Differential Protection at Talcher end.

3 Pole 1 2-Mar-18 16:15 2-Mar-18 19:19 Clogging of the mechanical filter of

Pole-1 valve cooling system at

Talcher.

4 Pole 1 7-Mar-18 09:38 7-Mar-18 10:25 Tripped due to external protection

tripping command as reported by

Talcher end

5 Pole 1 17-Mar-18 15:12 17-Mar-

N18

21:07 DC line differential protection

operated

6 Pole 2 17-Mar-18 20:29 17-Mar-18 21:07 While deblocking Pole-1, Pole 2 went

into ground return mode and power

flow got reduced to 150 MW.

HVDC Talcher-Kolar Related RVO operation January to March 2018

1 Pole 1 17-Mar-18 14:20 Tripped Several transients were observed in

HVDC Talcher –Kolar

2 Pole 1 20-Mar-18 06:32 20-Mar-18 13:43 Due to heavy fog in

Gazuwaka area. Total 6 nos

Transients were observed in

approx 1 hour

3 Pole 2 20-Mar-18 06:20 20-Mar-18 13:52

NLDC had observed Transmission licensees are required to take adequate steps to prevent

undesired outages of this HVDC link. There have been multiple pollution related trippings,

which warrant the replacement of porcelain insulators with appropriate polymer or

composite insulators, which have better resistance to flashovers from prevailing higher

pollution levels. NLDC communication dated 21st March 2018 in regard to frequent

trippings on HVDC Talcher – Kolar bipole had been communicated to PGCIL.

TCC deliberations

PGCIL agreed to look into the issues.


c) High flow on 400 kV KKNPP-Tirunelveli D/C line after commissioning of 400 kV

KKNPP-Tuticorin PS D/C line

In 42nd

SCPSPSR it was noted that, POSOCO had informed that POWERGRID had

commissioned above transmission system in 1st week of March 2018. But, with the

commissioning of 400 kV Kudankulam - Tuticorin PS D/c line (144 Km), more than 80%

of power generated from KKNPP (with both units in service) is flowing 400 kV

Kudankulam-Tirunelveli D/C section (72.5 km). It was further added that with more

generation at Coastal Energen and NTPL, there would be further uneven distribution of

flow on 400 kV KKNPP Tirunelveli and 400kV KKNPP- Tuticorin PS sections.

Additionally by commissioning of the new 400 kV lines connecting Tirunelveli wind


station to Tuticorin PS will further aggravate the situation. POSOCO stated that there is a

need to review the evacuation transmission system from KKNPP.

After deliberations, the issue had been referred for joint system study by CEA, CTU,

POSOCO and constituents of Southern Region. The proposal along with study results

would be discussed in next meeting of Standing Committee.

TCC noted the following

This issue had been discussed in the Joint Study Committee Meeting held on 10th

and

11th

May 2018 wherein it was noted that although the line loadings are uneven, there

is no issue regarding power evacuation from KKNPP even under contingency

conditions, as per planning criteria. Uneven loading of lines connected to U 1&2

would be studied while planning the evacuation for U 3&4.


d) Transmission Line constraints:

400 kV Nellore Pooling Station -Nellore D/C line

33rd

TCC: SRLDC requested SR-I to carry out modification at Nellore 400 kV S/S

as per Standing Committee decision.

400 kV Gooty-Nelamangala line & 400 kV Gooty- Somanahalli line

33rd

TCC: SRLDC informed that with commissioning of Tumkur - Bidadi line

loadings had come down. Downstream at Madhugiri & Yelahanka needs to be

expedited.

KPTCL informed that the prevailing constraint in 400 kV Hiriyur- Nelamangala

DC line with Twin Moose conductor would be reduced after commissioning of the

associated 400 kV transmission scheme of Yeramarus. Further, the newly

commissioned 400 kV Madhugiri-Bidadi D/C line also reduces the loading of 400

kV Hiriyur- Nelamangala D/C line.

400 kV Udumalpet- Palakkad D/C line

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

33rd

TCC: SRLDC informed that line loading is more when wind is more. With

commissioning of Pavagada-Hiriyur, loading may further increase. Hiriyur-

Mysore line needs to be expedited.

220 kV Bangalore Metro Network

33rd

TCC: KPTCL informed that they had planned the following 220 kV sub-stations

and lines which would provide relief to the existing congestion in the transmission

network of Bengaluru:

i. 2x500 MVA, 400/220 kV GIS sub-station at Peenya

ii. 2x500 MVA, 400/220 kV sub-station at Devanahalli(Under 2000 MW Tumkur

ultra-mega solar park scheme)

iii. 2x500 MVA, 400/220 kV sub-station at Mylasandra.

iv. 2x500 MVA, 400/220 kV sub-station at Dommasandra

v. 2x150 MVA, 220/66kV GIS station at ITI

vi. 2x150MVA, 220/66/11kV GIS station at Koramangala

vii. 2x150MVA, 220/66/11kV substation at Kumbalgodu

viii. 2x150MVA, 220/66/11kV GIS substation at Brindavan Alloys

ix. 2x150MVA, 220/66/11kV substation at Exora


x. 2x150MVA, 220/66/11kV GIS substation at HBR Layout

xi. 2x150MVA, 220/66/11kV GIS substation at Sahakari Nagar

xii. 2x150MVA, 220/66/11kV substation at Manyata Tech Park

xiii. 2x150MVA, 220/66/11kV sub-station at Whitefield.

xiv. 220/66/11kV Sub-Station at Nagarbhavi, Bangalore North Taluk

xv. 2x150MVA, 220/66/11kV substation at Nelamangala.

xvi. 220 kV DC line from Peenya to NRS in the existing corridor of 66 kV line.

xvii. 220 kV DC line from Peenya to Somanahalli in the existing corridor of 220 kV

SC line.

xviii. 220 kV 1000 Sq.mm UG Cable from Bidadi to Vrushabavathi Valley via

proposed 220kV Kumbalgodu.

xix. Construction of 220 kV multi-circuit, multi-voltage line between 400/220 kV

Somanahalli and 220/66 kV Subramanyapura s/s in the existing 66 kV line

corridor.

Overloading of 230 kV Shoolagiri-Hosur (TN)-Yerrandahalli-Somanahalli S/C line

33rd

TCC: KPTCL informed that after commissioning of 400/220 kV Mylasandra, the

loads of 220 kV Yerandanahalli sub-station would be taken on Mylasandra.

Constraints in Nagjheri PH evacuation

Constraints in Chennai 230 kV System

Overloaded 230 kV Lines in Tamil Nadu

220 kV Hyderabad Metro Network

e) ICT Constraints

765/400kV 2x1500 MVA Vemagiri ICTs

400/220 kV 2 x 315 MVA ICTs at Gazuwaka

41st SCPSPSR: After deliberations, members had agreed for an additional

400/220kV, 1x500 MVA ICT at Gazuwaka substation as ISTS.

400/220 kV 3 x 315 MVA ICTs at Vemagiri

41st SCPSPSR: APTRANSCO had 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

33rd

TCC: Devanahalli (under 2,000 MW Pavagada scheme) - Relieve loadings

of 400/220 kV ICTs at Nelamangala, Hoody and Hiriyur sub-stations.

Peenya & Huliyurdurga-- Relieve loadings of 400/220 kV ICTs at Nelamangala

sub-station.

400/220 kV 3 x 500 MVA ICTs at Somanahalli

33rd

TCC: Mylasandra - Relieve loadings of 400/220 kV ICTs at Hoody and

Somanahalli sub-stations.

T.K.Halli (Evacuation scheme of additional units of M/s UPCL. Approval yet to

be accorded by CEA) - Relieve loadings of 400/220 kV ICTs at Somanahalli,

Bastipura sub-stations.

400/220 kV 3 x 500 MVA ICTs at Hoody (In the special meeting held on 09.07.2018

to discuss pending issues in respect of Karnataka, KPTCL had informed that with the

commissioning of Yelahanka S/S, the loading was likely to come down)

33rd

TCC: Devanahalli (under 2000 MW Pavagada scheme) - Relieve loadings


Mylasandra - Relieve loadings of 400/220 kV ICTs at Hoody and Somanahalli

sub-stations.

400/220 kV 2 x 315 MVA ICTs at Guttur

33rd

TCC: Jagalur- Relieve loadings of 400/220 kV ICTs at Guttur and Hiriyur

sub-stations.

400/220 kV 2 x 315 MVA ICTs at Hiriyur


33rd

TCC: Devanahalli (under 2000 MW Pavagada scheme) - Relieve loadings


Jagalur- Relieve loadings of 400/220 kV ICTs at Guttur and Hiriyur sub-stations.

400/220 kV 1 x 500 MVA + 1x315 MVA ICTs at Narendra

400/220 kV 2 x 315 MVA ICTs at UPCL

400/220 kV 3 x 315MVA ICTs at Shankarapally

41st SCPSPSR: 1 x 500 MVA 400/220 kV transformer (4

th one) at Malkaram

S/S & Shankarpalli S/S approved

f) Other issues:

Vallur TPS (1500 MW) and NCTPS-II (1200 MW) generation is connected at 400 kV

Bus and no 230 kV path is available to give start up supply in case of Blackout. So

there is a need to provide 230 kV path.

National HVDC project of Lower Sileru-Barasoor line right of way has to be used for

New inter connection between SR & NEW Grids.

g) Overloading of 400 kV Nellore PS- Nellore D/C lines

In the 32nd

TCC the following had been noted:

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

TCC had 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.

Subsequently, the SPS had been implemented by PGCIL.

In 42nd

SCPSPSR after deliberations, it had been agreed to bypass Nellore PS – Nellore 400

kV D/C (Quad) line and Nellore – Thiruvalam 400 kV D/c (Quad) line at Nellore (PG) for

making Nellore PS – Thiruvalam 400 kV D/c (Quad) line to control loading on Nellore –

Nellore PS 400kV lines and control of short circuit levels.

SRPC noted the above and requested the concerned entities to take short term and

long term measures to overcome identified operational constraints.

18.9 Timely completion of Transmission Assets

PGCIL vide letter dated 26.07.2018 ( refer Annexure XXIX) had updated on transmission

assets which were commissioned /anticipated to be commissioned as discussed in 32nd

meeting of SRPC held on 22.08.2017 as detailed below:

I. Project: Transmission System for Ultra Mega Solar Power Park at Tumkur

(Pavagada), Karnataka -Phase-I

Sl. No. Asset description

Asset-1 LILO of one Circuit of 400 kV Gooty-Tumkur (Vasantnarsapur) D/C

line at Tumkur (Pavagada) pooling station.

Asset-2 New 400/220 kV pooling station at Tumkur (Pavagada) with 1 X

500MVA 400/220 kV ICT along with associated bays & equipment's.

Asset-3 LILO of second Circuit of 400 kV Gooty-Tumkur (Vasantnarsapur) D/C

line at Tumkur (Pavagada) pooling station along with associated bays &

equipment's.

Asset-4 1 X 500 MVA 400/220 kV ICT at 400/220 kV pooling station at

Tumkur (Pavagada) along with associated bays &equipments


Asset-5 1X 125 MVAR 400 KV Bus Reactor along with its associated bays and

equipments at 400/220 kV Tumkur (Pavagada) pooling station

Asset-6 LILO of 400 kV D/C Bellary -Tumkur (Vasantnarsapur) D/C (Quad

Moose) TL at Tumkur (Pavagada)pooling station along with associated

bays & equipments

Asset-7

(Anticipated)

3rd

500 MVA, 400/220 kV ICT at 400/220 kV pooling station at Tumkur

(Pavagada) along with associated bays &equipments

Asset-8

(Anticipated)

Tumkur (Pavagada) pool - Hiryur 400 kV D/C line along with

associated bays & equipments at both ends

Following are the details of DOCO of above mentioned lines/elements

Sl.

No Particulars

Line

length

(in

Kms)

Investmen

t Approval

date

CERC

qualifying

time

schedules

(in months)

Qualifyi

ng time

for the

project

DOCO

Commission

ed in

months

1 Asset-1 0.45

08.04.16

34

38

06.12.2017 20

2 Asset-2 NA 30 06.12.2017 20

3 Asset-3 0.45 34 01.02.2018 21 months 25

days

4 Asset-4 NA 30 14.02.2018 22 months 8

days

5 Asset-5 NA 30 31.03.2018 23 months 24

days

6 Asset-6 55.76 38 31.03.2018 23 months 24

days

7 Asset-7 NA 30 12.07.2018 27 months 9

days

8 Asset-8 109 34

Anticipated

DOCO

31.07.2018

28 months 24

days

(Anticipated)

Reference had been invited to the 32nd

meeting of SRPC held on 22.08.2017 read with

report of Special Meeting held on 01.09.2017 in SRPC Bangalore with participation from

CTU, SRLDC, states & SRPC. Utilization of these assets had been deliberated in the said

meetings and recommended for commissioning. Since this project is linked with the Ultra

Mega Solar Power Park at Tumkur (Pavagada), Karnataka, timely completion of above

assets was essential for facilitating the generator to commission and evacuate the power.

II. Project: Connectivity for Kudankulam 3 & 4 (2 X 1000 MW) with interstate transmission

system

Particulars: Extension of Kudankulam APP- Tirunelveli 400kV (Quad) D/C line to

Tuticorin pooling station along with associated bays & equipments at Tuticorin pooling

station.

Line

length

(in Kms)

Investment

Approval date

CERC

qualifying

time

schedules

Qualifying

time for the

project

DOCO Commissioned

66.093 12.01.16 38 months 38 months 10.03.18 26 months


Utilization of the above asset was also deliberated in the said referred Meetings and had

been recommended for commissioning.

III. Project: Green Energy Corridors: Inter-State transmission scheme (ISTS) -Part- A

Particulars: 2 X 400KV D/C (Quad) Tirunelveli Pooling Station -Tuticorin Pooling

station lines along with new 400/230KV (GIS) Tirunelveli Pooling substation with 2X 125

MVAR 400 KV Bus reactors along with associated bays & equipments at 400/230 KV

(GIS) Tirunelveli Pooling Station & associated bays &equipments at 400/230 KV

Tuticorin Pooling station and 2 X 500 MVA, 400/230 KV transformers along with

associated bays &equipments at new 400/230 KV (GIS) Tirunelveli Pooling substation

Line

length

(in

Kms)

Investment

Approval date

CERC

qualifying

time

schedules

Qualifying

time for the

project

DOCO Commissioned

2 X 12.05 17.04.15 38

months

38

months 10.06.18

37 months, 25

days

Utilization of the above asset had also been deliberated in the said meetings and

recommended for commissioning. As regards the utilization of ICTs, they are made ready as

per the timelines committed by Wind generators. Had the generators commissioned as per

the commitment, the ICTs would have been utilized and hence the utilization of ICTs is

beyond the control of POWERGRID. Further, there are no elements under POWERGRID

scope which is pending on account of which utilization is hampered.

TCC deliberations

TANGEDCO had pointed out that few upstream elements are to be completed by

SPPD/SPD and some transmission charges may need to be borne by the respective

SPPD/SPD. CTU should come out with specifics in this regard.

CTU had informed that LTA / part LTA operationalization is as per commissioning of

assets. Tariff is determined by Hon‟ble CERC and the specific billing to generator/DIC is

being clearly mentioned in the Order.

It was noted that this issue would be discussed in the special meeting of CTU and

constituents.

After deliberations, TCC recommended for timely completion of the above mentioned

assets.


SRPC also approved TCC recommendation for timely completion of the above mentioned

assets.

18.10 Edamon Bays Decapitalization

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had informed that with

upgradation of POWERGRID bays at 220 kV Edamon/KSEB station with hybrid

equipment, the removed equipment to be de-capitalized and the same to be taken over by

KSEB at depreciated cost. The matter needs deliberation.


TCC deliberations

KSEBL had agreed to take up the asset on depreciated cost after approval of the Board

and SERC. One of the reasons for delay in completing the PSDF project was belated

confirmation by PGCIL in this regard.

SR-II had clarified that would not pay O&M charges to KSEBL neither claim O&M

for this asset.


18.11 Power transfer reduction in Talcher- Kolar HVDC link

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had informed that Talcher-

Kolar HVDC link is being operated with extended power transfer capacity up to 2500 MW

for long time. Continuous operation at this rating may affect the performance of the

system. HVDC spares support from OEM M/s Siemens is becoming difficult since they

had declared end of life cycle for few components. Peak power transfer duration issue

needs deliberation for continuous life of link.

TCC deliberations

SRPC Secretariat had presented details of the flow on Talcher-Kolar HVDC link

(Annexure-XLIII). It was noted that the flow was above 2,400 MW for about 5% of

the time and above 2,000 MW for about 9% of time.

SR-II had informed that there was one incident where the pole was loaded beyond

2,400 MW for more than 10 hours. It was requested that the enhanced capacity may

be scheduled in two blocks of 5 hours each. Since there are a number of AC links,

enhanced capacity could be utilized during contingencies.

NLDC had agreed not to schedule at 2,500 MW beyond 10 hours a day. This aspect

was being monitored at NLDC. This capacity was being used during morning peak

hours when SR drawals are high and further when the angle between NR and SR is

exceeding 85 degrees. Generation balancing is also being resorted to.


18.12 Ratification of re-arrangement of Vemagiri constraint lines

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had stated that ratification of

rearrangement of Vemagiri constraint lines as given below is required:

a) Vemagiri GIS - Simhadri I and II

b) Vemagiri GIS - Vijayawada II and III

c) Vemagiri – Vemagiri(AP) I and II

As per the request of APTRANSCO, lines at Sl No (c) above were terminated in existing

bays at Vemagiri APTRANSCO to facilitate 400 kV KV Kota lines termination in new bays

constructed by Powergrid. Vemagiri constraint lines were charged on 1st March, 2

nd March

and AP lines on 8th

March respectively and are in service. While issuing trial operation

certificate, SRLDC had advised to ratify the above changes. Concurrence and ratification of


the same may be requested from SRPC. Copy of trial operation certificate was enclosed.

TCC recommended for ratification.

SRPC ratified the rearrangement.

18.13 250 MVA ICT at Bhadravathi Substation shifted from Moga Substation

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had informed that out of two

(2) nos. dismantled 250 MVA ICT at Moga S/S, one (1) no. ICT had been diverted to

Bhadravathi S/S. As agreed in 31st SRPC Meeting held on 25.02.2017, the said diverted

ICT was proposed to be provided at Bhadravathi at zero cost. However, in review petition

no. 182/MP/2017, Hon‟ble CERC has denied this ICT as regional spare. Therefore, instead

of zero cost, depreciated cost of diverted ICT and bay equipment cost needs to be shared

by Southern Region beneficiaries.

TCC recommended for approval.

SRPC approved TCC recommendation.

18.14 Utilization of 1 x 500 MVA, 400/220 kV ICT at Trichy S/S

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had informed that 1 x 500

MVA, 400/220 kV ICT at Trichy S/S is commissioned on 10.06.2017. However,

Extension 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.

TANTRANSCO informed that the ICT was in service since last year.

18.15 FSC at Cuddapah

In the OCC Meeting, it was noted that FSC at Cuddapah is out from February 2018

onwards. SR-I had informed that few cards were replaced for FSC at Cuddapah to make it

operational. Major rectification would cost a few crores, as per initial estimates.

In the 146th

OCC Meeting SRLDC had presented the study results of flows (Annexure-

XLIV) with FSC and without FSC of N‟Sagar-Cuddapah line. OCC forum had concluded

that major investment was not prudent, considering present flows. The same could be

recommended to TCC/SRPC to decide on future course of action. Further, if the FSC is not

rectified, it would be shown under Prolonged Outage.

TCC deliberations

TCC had recommended that additional major additional expenditure (in Crores) to

rectify the same was not desirable considering the present flows on the line. PGCIL

could take an appropriate call on decapitalization.

SR-I had stated that they would revert back on this matter.

SRPC deliberations

Director (O), PGCIL stated that the issue is being followed up with M/s Siemens to get

it rectified and it can be brought back in service. Other issue was to handle the

commercial implications if the asset is decapitalized. Since this was under 25 years

tariff structure there was some cost which was yet to be recovered. They were planning

a meeting with M/s Siemens and they would revert back.


SRPC observed that additional major expenditure was not recommended and PGCIL

could take same into account while finalizing future course of action.

19 SCHEDULING OF MACHKUND AND TB DAM

19.1 The issue of non-scheduling of Machkund and TB Dam power by APSLDC to Telangana

from 11.06.2017 had been taken up with APTRANSCO vide letter dated 04.07.2018

(Annexure-XLV) by SRPC. In this regard, the letter dated 02.07.2018 received from

TSTRANSCO on the subject was also enclosed.

19.2 The following had been noted in the TCC Meeting:

TSTRANSCO had taken up the issue with Machkund vide letter dated 18.07.2018

(Annexure-XLVI) requesting to suitably advice APSLDC to schedule the 53.89 %

share of power from Machkund to TS Discoms.

APTRANSCO had stated that APGENCO had observed that scheduling from these

stations would be commenced after TSDISCOMs clear the pending dues. They pointed

out that SCCL is not supplying coal if APGENCO stations dues are there.

APGENCO had stated that after bifurcation of AP & TS, Machkund share should be

with AP. Issue of pending dues had been taken up with TSDISCOMs vide letter dated

12.06.2017 and APGENCO had also approached National Company Law Tribunal.

TSTRANSCO had stated that these two projects could be viewed separately being

Inter-state projects and located in states other than AP and Telangana. As per IEGC,

SRLDC can take lead role in scheduling such Inter-state projects.

SRLDC had stated they would schedule the power to comply with IEGC provisions, if

required, but any intermediate solution between AP & TS was also welcome in this

case.

It was agreed that the issue would be discussed further in SRPC Meeting.

SRPC deliberations

CMD, APTRANSCO & MD, APGENCO informed that they are willing to schedule

these inter-state projects. However, TS Discoms should give categorical assurance and

some comfort that payments due for these two stations would be made without linking

with any other payment. For these two projects, there could be some sort of mechanism

to ensure that payment comes on regular basis.

Director (P & GO), TSTRANSCO stated that the CMD, TSTRANSCO would be

appraised in this matter and they would revert back.

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 III 800 August 2018 Unit-III: Trial operation


Stage-I successfully completed

between 30.04.2018 to

02.05.2018. Hon‟ble CERC

in Petition No.146/MP/2018

had extended the COD upto

31.08.2018.

Telangana STPP

Phase I

2 x 800 33rd

TCC:

U-I CoD August

2020

(Synchronization by

Mar 2020)

U-2 CoD Nov 2020

(Synchronization by

May 2020)

33rd

TCC:

MoP has allocated 85 % to

Telangana and 15%

retained as unallocated

subjected to approval of

competent Authority.

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.

33rd

TCC: GoK vide letter dated 19.07.2018 (Annexure-XLVII) had

sought status on share of allocation of power from Pudimadaka and

Ramagundam Stage IV ( rechristened as Telangana STPP Phase-I)

NTPC informed that MoP has allocated 50% to home state (AP) and

balance allocation has to be made.

NLC

New Thermal

Power Project

I 500 33rd

TCC :

Synchronization by

October 2018

II 500 33rd

TCC :

Synchronization by

December 2018

CEA (May 2018): LILO of Neyveli – Puducherry by July 2018, New

Neyveli TPP - Ariyalur (Villupuram) by July 2019.

SRTS-II vide letter dated 26.06.2018 (Annexure-XLVIII) had stated

that the LILO of could not be terminated at NNTPS Switchyard due to

non-readiness of associated bays at NNTPS switchyard which are under

the scope of M/s NLC. The said LILO line has been charged by cross

jumpering at dead end tower in NNTPS switchyard.

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had

informed that “Zero date” as per the Implementation agreement signed


between NLC India Ltd & POWERGRID for the subject asset was

01.05.2018. In accordance with the said agreement, POWERGRID has

completed the subject asset in all respects during April 18 and CEA

clearance for Energization of the subject asset was obtained on

27.04.2018, but could not be commissioned due to non-readiness of bays

at NNTPS generation switchyard. Their position and also the concerns

of non- charging of the line was communicated to M/s NLC vide their

letters dated 26.04.2018, 24.05.2018 & 20.06.2018. M/s NLC vide letter

dated 30.04.2018 informed that the bays would be made ready by

23.05.2018, however the bays were not made ready by M/s.NLC as

committed. Hence, as informed vide letter dated 20.06.2018, the subject

LILO line has been charged on 26.06.2018 by cross jumpering at dead

end tower in NNTPS switchyard and notified vide our notification dated

26.06.2018. Further, vide our letter dated.27.06.2018, NLC was again

requested to expedite the work and complete the bays immediately so

that the LILO line can be terminated at the NLC switchyard at the

earliest.

Further, the Status of commissioning of NNTPS Generation was

requested to be confirmed by M/s.NLC.

In view of the above, PGCIL had requested SRPC to recommend for

deemed DOCO of the above asset, please.

33rd

TCC: NLC informed that LILO would be completed by middle

of September 2018. Further these lines were for connectivity and not

for evacuation.

TCC endorsed cross jumpering at dead end tower at NNTPS switch

yard as it was critical line for Puducherry and tripping of lines

would lead to load shedding in Puducherry and TN.

Further it was noted that SRLDC had given for clearance of

charging for antitheft.

CTU stated that the sharing of the transmission charges would be as

per CERC order- most likely it would be borne by NNTPS.

TPS –II 2nd

Expn 1&

2

2 x 660 42nd

SCPSPSR:

Seeking connectivity for

1320 MW w.e.f. 01.04.2021

NPCIL

KKNPP 3 &

4

2 x 1000 32nd

TCC

U3: 2023

U4: 2024

41st SCPSPSR:

CTU had 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 33rd

TCC: March

2019

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had

informed that Kalpakkam PFBR - Kanchipuram 230 kV D/C Line of

POWERGRID was commissioned on 01.09.2012 under Transmission

System associated with Kalpakkam PFBR (500 MW) in Southern Region

as per the implementation agreement signed by BHAVINI and as agreed

in SRPC meetings and Standing committee meetings. CERC vide its

Order dated 24.09.2015, declined DOCO of the 230 kV BHAVINI–

Kanchipuram line due to non-readiness of Kanchipuram SS by

TANGEDCO. Kanchipuram SS is yet to be commissioned. During 32nd

TCC, TANTRANSCO informed that the S/S would come up by March

2018.

33rd

TCC : TANTRANSCO informed that the S/S would come up by

September 2018

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

33rd

TCC: As per the latest policy of GOI the issues regarding

conversion of the originally envisaged Cheyyur UMPP utilizing

imported coal to domestic coal UMPP is under discussion by MOP/ GOI.

The CEA has indicated a requirement of additional land of 767 acres if

domestic coal is to be utilized. The District / collector Kanchipuram has

been addressed by the Secretary/Energy Department in this regard.

In line with GOI policy for using domestic coal in place of imported

coal, the bidding documents are being revised and the bidding

process will be commenced by Ministry of Power.



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 2018-19

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 33rd

TCC: 2019-20

41st SCPSPSR: 2019

7 North Chennai Stage IV TN 2 x 800 33rd

TCC: 2019-20

8 Ennore TPS Exp TN 1 x 660 33rd

TCC: 2021

9 Ennore replacement TN 1 x 660 41st SCPSPSR: 2020

33rd

TCC: 2022-23

10 Udangudi Stage I TN 2 x 660 33rd

TCC: 2021-22

11 Udangudi Stage II TN 2 x 660 33rd

TCC: 2023-24

12 Udangudi Stage III TN 2 x 660 33rd

TCC: 2024-25

11 Uppur TPP (TBCB) TN 2 x 800 33rd

TCC: 2021-22

12 Manuguru PPP Telangana 4 x 270 33rd

TCC :

U1: April 19

U2: June 19

U3: Aug 19

U4: Oct 19

13 Kakatiya TPP Stage III Telangana 1 x 800 Not decided

14 Kothagudem TPS Phase

VII

Telangana 1 x 800 33rd

TCC : Aug 18

15 Damaracherla (Yadadri) Telangana 5x800 U 1 & 2: 33rd

TCC :

Commissioning Oct 2020 U 3 – 5 33

rd TCC :

Commissioning Oct 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

2018-19

5 Godhna TPP, Janjir –

Champa Dist,

Chhattisgarh

For

KAR

2 x 800 2018-19


22 REVIEW OF ULDC / SCADA/COMMUNICATION

22.1 Status of pending items is as follows:

Update as per Meeting on 13.03.2018 Status update

ICCP link failure/not stable

It was noted that respective Control Center would ensure that M/s GE take pro-active action to renew the licenses before the expiry

Updated communication network diagram to be submitted

by SR-I and SR-II to all SLDCs & SRLDC. Further any

changes done in the communication network needed to be

informed to all.

SR II had informed that

Necessary standby channels

are made available and

updated communication

network is ready.

Data outage after commissioning

Cross checking to be done with site daily values for newly

commissioned elements for a period of two week duration

from commissioning.

SR II : Complied and

SRLDC may check and

intimate any failures

RTU/SAS Maintenance/Upgradation

AMC need to be provided for all RTU/SAS gateways by

CTU/STU.

A life/functional assessment report and action plan by

PGCIL/ISGS on old RTUs would be prepared and

submitted to SRLDC/SRPC.

SR-II does not feel to have

AMC for SAS stations.

However, the conventional

RTUs, commissioned during

2001-02 are proposed to be

upgraded / replaced. The

offer obtained from GE for

upgradation and process to

be initiated

Backup Control Centre

Backup SCADA functionality testing frequency needs to

be done once in 6 months to ensure high availability of

data/preparedness to operate from Back up CC in event of

any contingency. Compliance report may be furnished to

SRLDC.

TN stated that communication network is being

strengthened to Backup CC. Once same is completed, TN

will do the testing.

Periodical testing was being

carried out by SRLDC and

KSEBL.

33rd

TCC: PGCIL would

be floating new combined

Open Tender for Backup

SLDCs for AP (Tirupati),

TS (Warangal) along-with

few other states.

ICCP with NTAMC

PGCIL had confirmed that due to cyber security concerns

data would not be extended to SRLDC from NTAMC

ICCP.

Functional requirement of the requisite data by SRLDC

would remain, which needed to be ensured by PGCIL.

SRLDC would furnish the list of telemetry points that have

to be extended to PGCIL within 10 days, and within 1

month PGCIL would come out with a detailed plan to be

completed within 6 months (October 2018)

SR II : Additional data

points have been received

from SRLDC and action is

being taken to extend the

inputs by Oct 2018

Modification of EMS package

TSTRANSCO had received estimate of Rs 47 lakhs and

the contract was being firmed up.


Sparing of Fibre in Central Sector Project

TANTRANSCO had again requested for sparing of fibre

in Central Sector Project.

SR-II stated that request for

sparing of fibre in new FO

links could be communicated

for consideration.

33rd

TCC: TANTRANSCO

and PGCIL agreed to

deliberate bilaterally.

VC issues

TSTRANSCO Video Conference issue at TSSLDC. There

was disturbance in Video Conference at TS end when

connected to SRLDC.

33rd

TCC: Issue had been

resolved.

Puducherry would take up VC requirement in the financial

year 2017-18.

TCC deliberations

SRLDC had stated that DCPC maintenance was to be carried out diligently.

Tamil Nadu had agreed to compute independent ISTS drawl which could be regularly

verified with SRLDC drawl figures.


22.2 ICCP links had failed on 07.02.2018, 08.02.2018 and 23.02.2018. To address the issues, an

urgent meeting was called on 13.03.2018 (MOM available at SRPC website). The

actionable points needed to be complied by all the concerned entities. Further, a special

meeting with participation from M/s GE was held on 23.05.2018 (MOM available at SRPC

website). The following had been agreed in the Meeting:

A formal procedure to be followed during ICCP failure would be developed. Timely

renewal of the certificates would also be included in the procedure.

Procedure for database mismatch correction, duration of making changes and

validation of the same to be formulated and made part of procedure such that the

database between control centers are in sync and error logs are cleared in timely

manner.

SR-I & SR-II were requested to check all ICCP links for healthiness through ping

check and testers in consultation with SRLDC and constituents on periodic basis.

It was pointed out that all states need to compute a parallel ISTS drawal on different

philosophy independent of points being used by SRLDC. This will ensure consistent

verification of the ISTS drawal and will be helpful in contingencies. AP & TS

informed that they were following such procedure and independent ISTS drawal was

being computed. Discrepancy needed to be informed to SRLDC for early

rectification.

GE offered to conduct quarterly meetings on AMC and other SCADA related issues

which could be conducted through VC or at a common site.

TCC deliberations


AP & TS had expressed concern on frequent failure of ICCP links and even the

duration of outages was longer. They stated that they would consider dedicated

leased line from SLDC to SRLDC.

SR-II, PGCIL had informed that besides two OFC connectivity (Somanhalli -

SRLDC, 2nd

connectivity was established 3 months back through HAL) they were

utilizing bandwidth from Powertel (Somanhalli-SRLDC) in which major data was

protected. In addition, fourth connectivity from Hebbal to SRLDC would also come

up within a month. Few issues like license, configuration, architecture, power supply

etc (addressed after the meetings) had also contributed towards ICCP link failures.

Recently the redundancy had been affected due to OFC failure on account of BBMP

works.

SRLDC had stated that they would also examine the connectivity & take appropriate

action.

It was noted that OFC link failures at two locations in KPTCL portion were attended

but the link was yet to come up.


22.3 Commissioning of alternate communication link to SRLDC through KPTCL

underground fibre link

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had informed that and placed

on record appreciation of KPTCL that the alternate communication link to SRLDC has

been established and commissioned through KPTCL underground fibre link; HAL – A

Station during April 2018. POWERGRID had extended sincere thanks to KPTCL for

sparing fibres in Bengaluru intra-city underground fibre links for establishing reliable

communication network for effective grid operation of Southern Region.

22.4 Signing of Agreement / MOU between Powergrid and Constituents for

replacement/upgradation of RTUs

With regard to replacement of S-900 RTUs in Northern Region, SRPC vide letter dated

24.05.2018 (Annexure-XLIX) had communicated the concerns to ED (LD & C),

PGCIL and requested that a review exercise on the matter may kindly be taken up for

SR also.

SR-I & SR-II had clarified that the CPU card was to be replaced to handle the present

communication requirements for various applications. The ISG stations requirement of

replacing the CPU card could be covered in the scope of PGCIL works on payment

basis. ISG stations were requested to revert back.

Letter dated 15.06.2018 from PGCIL (LD&C) in this regard is given at Annexure-L,

SR-II vide letter dated 27.06.2018 (Annexure-LI) had informed that it is proposed to

replace the CPU card in all the RTUs of POWERGRID stations (SR-II-13 no, SR-I-09

no) and the estimated cost per station is approximately Rs.6,51,000/- (Supply:

Rs.4,66,000/- & Services: Rs.1,85,000/-) excluding GST @18 %. However, final price

shall be arrived after due negotiations with GE as per POWERGRID standard

procurement policy.

Further, the issue had been taken up by PGCIL vide letter dated 26.07.2018 (refer

Annexure-XXIX)


TCC deliberations

NLCIL had requested that their requirement may be covered along with SRII, PGCIL

proposal and they would reimburse the amount.

Other ISGS were also requested to kindly furnish their concurrence/ requirement.

SR-II had informed that they were in process of procuring and the requirement to be

communicated at the earliest.

AP & TS had stated that the rates seemed to be on the higher side and subsequently, this

may impact their RTU card procurement.

SRPC deliberations

Director (O), PGCIL informed that the replacement may not serve for long. Since the

replacement of the cards and the new RTU were nearly costing the same, PGCIL would

reconsider replacing the RTU rather than replacing the cards. They would come out

with a proposal shortly.

SRLDC informed that the replacement of RTU has been agreed in WR also. The

transducers would not be replaced.

It was agreed that POWERGRID would take a call on the matter.

23 URTDSM (PMU) PROJECT IN SOUTHERN REGION

23.1 URTDSM Phase-I project is nearing completion. The progress is being reviewed in the

Special Meeting/OCCM. A Special Meeting was conducted on 13.03.2018 to review the

progress. The updated status in this regard is given at Annexure-LII.

23.2 Feedback on currently installed analytical applications (LSE, VADR, Supervised Zone-3

Distance protection) and installation of pending Powergrid analytical application.

23.3 PGCIL had requested all constituents to submit revised PMU requirement, if any, for

Phase-II considering availability of Wide Band nodes. APTRANSCO, TSTRANSCO &

KSEBL vide had submitted PMU requirement for Phase-II.


24 EMERGENCY RESTORATION SYSTEM (ERS)

24.1 Requirement of ERS had been outlined in MoP letter dated 05.12.2014. The status was

being monitored by Secretary (Security). Status update is given below please:

Transmission

Utility

Requirement as

per MoP

Existing Status/Remarks

APTRANSCO 3 2 ERS III would be taken up

through own funding.

33rd

TCC: Under process

TSTRANSCO 1 Tender floated; would be taken

up for PSDF funding.

33rd

TCC: Tendering under

progress.

KPTCL 2 2

KSEBL 1 Tenders to be floated. Would be


taken up for PSDF funding.

33rd

TCC: Agreed to take up

through own funds

TANTRANSCO 2 As per Minutes of BLTC held on

03.01.2017, procurement is put

on hold. Would require PSDF

funding.

33rd

TCC: On clarification from

NPC that PSDF funding would

not be possible and as it was

mandatory as per CEA

regulation, TANTRANSCO

stated that they would also take

up providing ERS through own

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)

33rd

TCC: Under inspection.

Expected by January, 2019.

25 ADOPTION OF UNIFORM PROCEDURE TO PREPARE MERIT ORDER

DESPATCH LIST

In the Sub-committee Meetings it was noted that different methods are being followed by

states to prepare Merit Order Despatch List. It was therefore suggested that common

guidelines for preparation of Merit Order Dispatch List may be formulated for the benefit of

all.

This issue had been discussed in 38th

Meeting of Commercial Sub Committee, wherein

some issues like, ISTS loss, incentive, compensation, URS, billed MOD, ERC approved

MOD, EC computation for state vs central generators, flexibility in LTA/MTOA, MOD on

D-3 (non-availing of STOA) etc. It was agreed to discuss the nitty gritty of the issue by a

Sub Group, and then it could be taken up with CEA/NLDC.

SRPC noted that this issue would be discussed further in sub Committee Meeting.

26 PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR

26.1 Status of implementation of Bus / Line Reactors / Dynamic Compensation approved in the

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

below please:

Entity Bus Name Status REMARKS

KPTCL

Hoody Reactor erected on

platform.

2018-19

Nelamangala Reactor erected on

platform

2018-19


Entity Bus Name

Capacit

y in

MVAR

Approved

in Type Remarks

PGCIL

Yelahanka 2x63 40th

SC 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

Kurnool 765 kV 2 x 240 42nd

SCPSPSR

Raichur 765 kV 2 x 240 42nd

SCPSPSR

Thiruvalam 765

kV 2 x 240 42

nd SCPSPSR

Pavagada 2 x 125 42nd

SCPSPSR

Nellore (PG) 2 x 50

42

nd SC

Line

to

Bus

Hosur 63 to 125 42nd

SC Bus

Madhugiri 63 to 125 42nd

SC Bus

Dharmapuri 125 42nd

SC Bus

Hiriyur 125 42nd

SC Bus

Pugalur 125 42nd

SC Bus

Pugalur HVDC 2 x 125 42nd

SC Bus

APTRANSC

O

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.

Uravakonda 125 42nd

SC Bus

Uravakonda 80 42nd

SCPSPSR

Jammalmadugu 80 42nd

SCPSPSR

Sattenapalli 125 42nd

SCPSPSR

Rachagunneri 125 42nd

SC Bus

Hindupur 80 to 125 42nd

SC Bus

APGENCO

VTPS Stage IV 125 39th

SC

APGENCO informed that

reactor enquiry was being

taken up.

It was noted that this

reactor was different from

the APTRANSCO reactor.

Polavram HEP 2 x 125 42nd

SC Bus

KPTCL Davanagere 125 39th

SC 41st SCPSPSR:


Talaguppa 125 39th

SC

Requirement reaffirmed.

Special meeting

09.07.2018 & 33rd

TCC:

Approved in TCCM,

estimate under

preparation.

C N Halli 2 x 125 42nd

SC Bus 42nd

SCPSPSR: KPTCL

stated that they will send

their consent within 15

days of the meeting.

33rd

TCC: C N Halli –

Land identified.

Jagalur – Work under

progress.

Jagalur 2 x 125 42nd

SC Bus

KPCL

Yeramarus 125 42nd

SC Bus

Bellary 2 x 125 42nd

SC Bus

KSEBL Wayanad 125 42nd

SC Bus

TANTRANS

CO

Almathy 125 39th

SC Specification under

process Manali 125 39

th SC

Kayathar 125 39th

SC

Kamuthi 2 x 80 42nd

SCPSPSR

Virudhnagar

(765 kV)

2 x 330 42nd

SC Bus

2 x 330 42nd

SC Line

Coimbatore (765

kV) 2 x 240 42

nd SC Line

Kayathar 125 42nd

SC Bus

Kamuthi 125 42nd

SC Bus

Thappagundu 125 42nd

SC Bus

Kadaladi 125 42nd

SC Bus

Parali 125 42nd

SC Bus

Arni 2 x 125 42nd

SC Bus

Velalividu 125 42nd

SC Bus

TANTRANS

CO/

TANGEDCO

Mettur 125 39th

SC

To be diverted from

Palavadi and works to be

taken up.

TSTRANSC

O

Mamidipally 125 36

th SC

Bus

Commissioned on

23.02.2018

Asupaka 80 42nd

SCPSPSR

Suryapet 125 42nd

SC Bus

42nd

SCPSPSR:

TSTRANSCO stated that

they will send their

consent within 15 days of

the meeting.

Raidurg 2 x 125 42nd

SC Bus

Kamalapuram 125 42nd

SC Bus

Narsapur 125 42nd

SC Bus

Maheshwaram 125 42nd

SC Bus

Tippapur 125 42nd

SC Bus


Manikonda 125 42nd

SC Bus

Jangaon 125 42nd

SC Bus

Choutuppal 125 42nd

SC Bus

Yellampalli 125 42nd

SC Bus

TSTRANSC

O/

TSGENCO

Srisailam LB 125

39th

SC

42nd

SCPSPSR: CEA

Meeting (06.02.2018)- It

was decided that a team

comprising officers from

CEA, CTU and

TSTRANSCO would visit

SLBHES switchyard to

explore the feasibility to

accommodate the reactor

(125 MVAR).

NPCIL Kaiga 2 x 125

Bus

One reactor by December

2019.

2nd

reactor soon after 1st

reactor.

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 vide letter dated 09.07.2018 (Annexure-LIII) had taken up with PCKL

the issue of according approval since these reactors had been approved by the

Standing Committee and Karnataka SLDC had also endorsed the urgent

requirement.

KAR SLDC vide letter dated 01.08.2018 (Annexure-LIV) addressed to the

Chief Engineer (E) Planning and Coordination, KPTCL had reaffirmed the need

for 2 x 125 reactors at UPCL for operational requirements.

33rd

TCC:

PCKL had informed that approval may not be essential as UPCL had

already included this asset in their tariff petition filed before CERC. The

requirement would be put upto PCKL Board.

KPTCL has stated that technically the requirement of Reactor was

justified, and they would take pro-active steps in this regard.

UPCL had stated that since 29.09.2017 to 11.07.2018 Unit 1 & 2 had

absorbed in 1,500 blocks and 1,251 blocks respectively and units were

absorbing reactive power up to 80 MVAR and it had gone up to 138

MVAR. As per PPA, there was no obligation on behalf of UPCL to absorb

MVAR beyond 420 kV. In more than 300 cases, voltages were beyond 420

kV at UPCL bus. Approval from PCKL would facilitate early

commissioning.

NLC NLC TPS-II 2

nd

Expansion 125

42nd

SC Bus


SRPC requested the entities to kindly expedite commissioning of reactor, since high voltage

was being observed on sustained basis.

26.2 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 33rd

TCC: 1st

STATCOM

expected at site

by Oct’18 &

2nd

expected by

Nov’18.

Civil works

are in

progress;

commissioning

by Mar’19.

Trichy 12.5/

18.0

+ 200 MVAR 2x125 1x125

26.3 Reactive Power Planning

26.3.1 Status of Capacitor installation in Transco/Discoms is given below:

Utility Reactive Power Planning Voltage

level

Remarks

APTRANS

CO

Kadapa: 244.8 MVAR

Vijayawada: 122.4 MVAR

Visakhapatanam:158 MVAR

On 33

kV side

0 MVAR commissioned

0 MVAR commissioned

0 MVAR commissioned

APSPDCL 640 MVAR 2 MVAR commissioned

APEPDCL 276 MVAR 54 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

43.5 MVAR commissioned

Mysore Tr. Zone: 60.9

MVAR

60.9 MVAR commissioned

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

259 x 2 MVAR

105 x 1 MVAR commissioned

TSSPDCL 204 x 2 MVAR

58 x 1 MVAR

Nil

KSEBL 360 MVAR 66 kV Works will be taken up after

approval. 11kV


TANGEDC

O

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.

SRPC requested the entities to kindly expedite the commissioning.

26.4 PSDF – Funding of the schemes of the state utilities for installation of capacitors in

the state network at transmission / distribution network

26.4.1 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).

26.4.2 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 had submitted the same to NLDC for further needful action. SRPC vide

letter dated 16.01.2018 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.

26.4.3 Convener, TESG & Consultant, NLDC vide letter dated 21.05.2018 (Annexure-LV)

had furnished the extracts of the 38th

Meeting of TESG held on 26.02.2018 and

requested for needful with regard to the observations. With respect to SR it had been

mentioned that the Capacitor Study Report submitted by SRPC prepared by CPRI dealt

only with transmission level (132 kV and 220 kV voltage level) whereas requirement

was also for distribution level (33 kV and 11 kV).


SRPC vide letter dated 29.05.2018 (Annexure-LVI) had submitted the reply in this

regard to Member Secretary, Appraisal Committee.


26.5 Low voltages were observed in Bengaluru Area and Central/ North Kerala with

Udumalpet and Arasur areas

A study was undertaken and the following are the recommendations:

Low Voltage in Bangalore Area was likely due to heavy drawl of MVAR to the order

of about 1,000 MVAR. In the Special Meeting held on 09.07.2018, KPTCL had

informed that 784 MVAR capacitors were expected to be commissioned by

December 2018 (153 breakers were expected by Aug 2018). Further KPTCL

confirmed that they would discuss the issue with BESCOM and identify measures to

minimize the impact of MVAR drawal from ISTS grid.

Low Voltage in Kozhikode was due to operational error in switching Capacitor.

KSEBL had assured that in future, while drawing through Kozhikode ICTs, they

would also factor the current voltage situation at Kozhikode Bus.

Low Voltage in other parts of Kerala was due to low short circuit levels. Improvement

in voltage would be possible with commissioning of 400 kV D/C from Tirunelveli to

Cochin. This issue was under deliberation with KSEBL.

Low voltage in Udumalpet and Arasur areas.

TCC deliberations

KPTCL had assured that identified capacitors in Bengaluru area (784 MVAR) would

be commissioned by Dec, 2018.

TCC had suggested KPTCL, KSEBL & TANTRANSCO to take appropriate steps to

address the issue.


27 NON-AVAILING OF OCC APPROVED SHUTDOWN

27.1 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 please:

Entity Feb-18 Mar-18 Apr-18 May-18 June-18 July-18

Availed % with respect to the OCC approved outages

AP TRANSCO 35 40 72 75 77 65

KPTCL 83 75 57 60 100 75

KPCL 100 - - - - -

KSEBL 100 100 100 100 100 -

TANTRANSCO 49 - 35 40 70 64

TSTRANSCO 56 100 64 70 70 70

PGCIL, SR1 96 100 64 68 43 92

PGCIL, SR2 45 75 33 80 72 73

NTPC 100 100 100 100 75 0

NLC 100 100 100 50 67 -


27.2 It was noted that some shutdown proposals were being made even on the day of the OCC

Meeting. Constituents were kindly requested to plan outages more diligently and increase

coordination with the field and project officials.

27.3 In the 141st Meeting of OCC, it was agreed that mid review outages would be approved only

after confirmation from SLDCs of AP, KAR, KER, TN & TS. Proposals would be posted on

outage group and after confirmation of states; the approved shutdowns will be uploaded on

SRPC website.

TCC deliberations

Only outages uploaded on (D-3) in SRLDC portal would be approved.

Only emergency outages would be considered in real time.


27.4 Delay in restoration of transmission elements

Narendra ICT-II was taken out by SR-II, PGCIL on 05th

March 2018 during the peak

months. The approval of the Senior Management of Karnataka had not been taken for

availing the shutdown. KPTCL had expressed serious concern since a couple of

disturbances involving load loss of about 1,000-1,500 MW had occurred in that area and

there was high loading on the available Narendra ICT. SR-II had restored the ICT on

14.04.2018, though the approved date for revival was 31.03.2018.

Shutdown of 400 kV of Neyveli-Puducherry was also extended beyond the approved dates

(12.04.2018-22.04.2018) by PGCIL (revived on 29.04.2018). During such time the

Puducherry region as well as Cuddalore area in Tamil Nadu was operating under reduced

grid reliability.

It was noted in the OCC Meeting that for any reconfiguration etc, similar procedure as

adopted for new elements needs to be followed by all the concerned entities.

A Meeting in this regard was also held with SR-II, PGCIL on 17th

April 2018. The

actionable points (applicable to all the concerned entities) had been communicated vide

letter dated 18.04.2018 (Annexure-LVII).

NTPL - - - - - -

NPCIL 33 0 - 100 100 -

PNMTL 0 - - - - 50

CEPL 100 - - - - -

MTL 0 - - - - -

RSTCL 0 - - - 0 -

UPCL 0 - - - - 80

MEPL - 0 - - - -

Total 53 66 54 64 68 69


As noted in the earlier SRPC/TCC meeting, PGCIL / Transmission licensee would

endeavour to deploy ERS for critical outages. Further, PGCIL was to furnish revival

status 2-3 hours prior to scheduled time of revival.


28 COMPLIANCE STATUS OF PHASE-I AND PHASE-II OF PROTECTION AUDIT

RECOMMENDATIONS

With reference to the Petitions filed by KSEBL (88/MP/2016) and KPTCL (135/MP/2016)

seeking further time-extension for completing their respective Protection Audit

Recommendations (PAR), the final Order of Hon‟ble CERC disposing of petitions was issued

on 15.12.2016. In this Order, the Commission, apart from granting last-chance time-extensions

to various SR-Constituents, had also directed SRPC to monitor the status of completion of

PAR regularly in PCSC meetings and submit bi-monthly report to the Commission confirming

the completion of Phase-I and Phase-II of PAR of the Constituents of Southern Region.

In this regard, based on the information furnished various Constituents, a summary table

showing the compliance status of various SR-Constituents as on 07.08.2018 is given below,

please:

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 80.00 Based on the status furnished,

timeline for complying with the

remaining pending

recommendations (3 in no.) is

31.08.2018.

2 APGENCO

(Thermal)

30.07.2017 --- 83.33 Based on the status furnished,


remaining pending


31.08.2018.

3 APTRANSCO 31.03.2017 --- 98.57 Based on the status furnished, the

lone pending recommendation is

expected to be completed by

31.10.2018.

4 TSGENCO

(Hydel)



remaining pending


30.09.2018.

5 TSTRANSCO 31.03.2017 31.03.2017 89.77 Based on the status furnished,


remaining pending


31.08.2018.


6 KPTCL 31.05.2017 31.05.2017 78.87 Based on the status furnished,


remaining pending


30.09.2018.

7 TANGEDCO 31.12.2017 31.12.2017 80.55 Based on the status furnished,


remaining pending


30.09.2018.

8 TANTRANSC

O



remaining pending


31.12.2018.

9 KSEBL 30.11.2016 31.12.2017 97.4 Based on the status furnished,


remaining pending


31.08.2018.

10 NPCIL

(MAPS)

31.01.2017 --- 88.89 Based on the status furnished,

timeline for complying with the lone

pending recommendation is

30.09.2018.

All above SR-Constituents (esp. KPTCL & TANTRANSCO) were requested to complete their

respective pending PAR at the earliest. The 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.

SRPC deliberations

This being a CERC monitored activity, all the constituents were requested to kindly

complete the pending works at an early date.

MS, SRPC informed that in Western region, WRTS-I & II had gone for third party

protection audits for 8 sub-stations /7 sub-stations respectively through CPRI and same

procedure could be adopted in SRTS-I & II. Though audits are being carried out in SR,

there was a physical limitation on account of manpower constraints. It would therefore be

prudent for PGCIL to go for third party audits in SR.

Director (O), PGCIL informed that internal protection audits are regularly carried out in all

PGCIL sub-stations. However, they would also contemplate third party protection audits for

few of its sub-stations in SR.

29 IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT

SYSTEM (PMS) FOR SOUTHERN REGION

Based on the approval of SRPC in their 26th

Meeting held on 20th

December, 2014 at

Visakhapatnam, implementation of Protection Management System in Southern Region [Web-

based Management Software and Protection Setting Calculation Tool for Southern Region] had

been undertaken through PSDF funding. The project was awarded through open bidding


process to M/s PRDC Pvt. Ltd. (PRDC) on 09.08.2017. 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.

The detail of the project implementation including Milestone-wise status is given at

Annexure – LVIII for kind reference.

In this regard, a protocol on implementing & using Protection Management System and giving

an integrated view of the project had also been circulated to all SR-Constituents vide SRPC

letter dated 20.04.2018. Data collection by physical field visits of the stations in Tamil Nadu,

Puducherry, Kerala, and Telangana had been undertaken by PRDC. Even though this process

had been completed, all the data sought as per stipulated formats for modelling in PMS has

been pending from certain stations. In view of the time-bound nature of the PMS project,

monthly review Meetings are being planned regarding submission of pending PMS data to

PRDC.

Automated Fault Analysis System (AFAS) envisaged under PMS project was successfully

implemented for 400/ 230 – 110 kV Palavadi SS (Pilot Station), and was put under service with

effect from 18th April, 2018.

In this regard, the issues which have potential to delay the project like partial or late

submission of required data for building Protection Database by various Utilities, furnishing

details of the models employed for Governor, AVR & PSS by Generating Utilities, and

furnishing all required information for updating 132/ 110/ 66 kV power network of SR-grid

had been high-lighted.

With respect to updating 132/ 110/ 66 kV Network of SR-grid, considering the time-bound

nature of the project, and the criticality of the issue, it was agreed that SRPC Secretariat would

take steps to resolve it on priority basis by involving all stakeholders by seeking nominations of

suitable Nodal Officers from SRLDC and SLDC & STU of all states, who have thorough

knowledge of their respective 132/ 110/ 66 kV network. It was also decided that that these

members would participate in the Network Reconciliation Meetings that would be held state-

wise at SRPC Secretariat, Bengaluru, and would take lead in updating/ correcting connectivity

of each grid-connected substation at 132/ 110/ 66 kV level in their states.

All SR-Constituents (Genco’s/ Transco’s/ LDC’s/ ISGS Utilities/ ISTS Utilities/ IPP’s/

other Generators/ etc.) were requested to kindly extend full-fledged cooperation in terms

of furnishing required information/ data for setting up & maintaining protection

database, and ensure that PMS project is made operational by the targeted time-line of

9th

February, 2019.

SRPC noted the same.


30 COMPLIANCE STATUS OF NEW PROTECTION AUDIT RECOMMENDATIONS

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, wherein certain recommendations were also given for each of these stations for

compliance.

Subsequently, protection audit of various stations in SR had also been regularly conducted by

SRPC teams in line with CERC Order dated 27.04.2015 in respect of APTRANSCO Petition

No.95/MP/2015 and CERC Order dated 14.05.2015 in respect of TSTRANSCO‟s Petition

NO:83/MP/2015. So far, protection audit of 11 stations was carried out during the period

December, 2016 – July, 2018, wherein certain recommendations were also given for each of

these stations for compliance.

The list of Stations audited & compliance % of the recommendations given is given below for

kind reference:

Sl. No. Name of the Station Period of Protection Audit Compliance %

APTRANSCO 51.31

1 400/ 220 kV Narnoor SS 16–18 February, 2016

64.52

2 400/ 220 kV Uravakonda SS 5-6 April, 2018 38.10

TSGENCO (Thermal) 62.41

1 (i) 220 kV KTPS (O&M) 14-16 March, 2016 52.78

1 (ii) 220 kV KTPS (Stage-V) 14-16 March, 2016 40.91

1 (iii) 220 kV KTPS (Stage-VI) 14-16 March, 2016 93.55

TSTRANSCO 81.82

1 400/ 220 kV Shankarapally SS 20-21 March, 2017 81.82

KPCL 48.31

1 400 kV & 220 kV Raichur TPS 8-10 June, 2016 46.34

2 220 kV Nagjheri PH 14-16 July, 2016 54.84

3 220kV Sharavathy GS 30-31 October, 2017 43.75

KPTCL 65.25

1 400/ 220 kV Guttur SS 4-6 May, 2016 79.07

2 400/ 220 kV Nelamangala SS 8–10 February, 2016

51.43

KSEBL 34.88

1 220 kV Edamon SS 18-20 January, 2016 34.88

TANTRANSCO 38.73

1 400/ 230 kV Alamathy SS 4-6 January, 2016 51.61

2 230 kV Alundur SS 17 December, 2016 31.25

3 400/ 230 – 110 kV Palavadi SS 14-15 May, 2018 33.33

Puducherry ED 08.79


1 230/ 110 kV Villianur SS 10 July, 2017 9.68

2 230/ 110 kV Bahour SS 11 July, 2017 7.89

PGCIL (SR-I) 48.57

1 400 kV & HVDC Gazuwaka SS 28-30 December, 2015

50.00

2 400/ 220 kV Gooty SS 12th,13

th and 15

th February,

2016 50.00

3 765/ 400 kV Nellore PS 19-20 June, 2017 80.00

4 765/ 400 kV Maheshwaram SS 8-9 February, 2018 14.29

PGCIL (SR-II) 63.75

1 400 kVHosur SS of PGCIL (SR-II) 9-11 December, 2015 25.00

2 400 kV Tirunelveli SS 8th,

,9th and 11

th January, 2016

50.00

3 400 kV Alundur SS 16 December, 2016 100.00

4 400/ 220 kV Kozhikode SS 21-22 December, 2017 80.00

NTPC 85.00

1 400 kV Ramagundam STPS 18-20 February, 2016 85.00

NPCIL 33.33

1 220 kV Kaiga GS 4-6 April, 2016 33.33

NLCIL 56.25

1 400 kV NLC TPS-II Station 8–10 February, 2016

56.25

Details of the stations audited during the period March, 2018 - June, 2018 are given below for

kind reference:

Remarks given by the audit teams for the above stations are enclosed at Annexure - LIX for

kind reference.

APTRANSCO, TSGENCO, TSTRANSCO, KPCL, KPTCL, KSEBL, TANTRANSCO,

Puducherry ED,NTPC (RSTPS), NPCIL (KGS), NLCIL, PGCIL (SR-I) & PGCIL (SR-II)

were requested to kindly take suitable action to comply with their respective pending

remarks.


31 AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE

TRANSMISSION LINES OF SOUTHERN REGION

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

Sl. No. Name of the Station

Audited

Period of Protection

Audit

Composition of Audit

Team

1 400/ 220 kV Uravakonda SS

of APTRANSCO

5-6 April, 2018 SRPC, SRLDC &

PGCIL (SRTS-I)

2 400/ 230 – 110 kV Palavadi

SS of TANTRANSCO

14-15 May, 2018 SRPC, SRLDC &

PGCIL (SRTS-II)


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.

Further, provision for Auto-Reclosure is also mandated by Regulation 43 (4) (c) of CEA

Technical Standards for Construction of Electrical Plants and Electric Lines, 2010, which has

force of law. Therefore, it is in the interest of grid security that all Constituents implement

auto-reclosure feature on all 220 kV & above transmission lines in their respective control

areas. Any exceptions in this regard need to be properly justified.

In this connection, logics for implementing A/R have been clarified in various PCSC Meetings,

and their implementation status is being monitored periodically. 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.

Status of implementation of A/R 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 76th

Meeting of PCSC held on 26.07.2018. The details are

enclosed at Annexure – LX for kind reference.

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 requested to take action accordingly to implement A/R on their lines.


32 COMPLIANCE STATUS OF PCSC RECOMMENDATIONS

All trippings involving 220 kV & above system on account of mal-operation/ non-operation

of protection systems in place are regularly discussed in the monthly held meetings of

Protection Coordination Sub-Committee (PCSC) meetings of SRPC with a view to identify

their root cause and scrutinize 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 being suggested/ recommended for compliance by concerned

Constituents. These recommendations, communicated vide Minutes of the PCSC meetings,


are also being monitored in these meetings for compliance by concerned Constituents.

In this regard, the latest status of implementation of PCSC recommendations pertaining to

various SR-Constituents for necessary compliance is enclosed at Annexure – LXI.

33 COMMERCIAL COMMITTEE ISSUES

33.1 Following issues were brought to the kind attention of TCC/ SRPC:

Transmission Charges pertaining to Kudgi STPS

Chairperson, SRPC vide letter dated 22.03.2018 (Annexure-LXII) had taken up the

issue of changing the LTA quantum from 2392.49 MW to 2262 MW with CMD, PGCIL.

Vide letter dated 28.06.2018 (Annexure-LXIII) COO, (CTU-Plg), had requested NTPC

to furnish the following details;

a) How the LTA quantum of 2392.49 MW has been arrived at when LTA was

sought against the installed capacity of 2400 MW and

b) Computation of revised LTA

NTPC vide mail dated 03.07.2018 had informed that the information sought had already

been communicated vide mail dated 24.04.2018 and it was again forwarded.

CTU vide letter dated 25.07.2018 (Annexure-LXIV) had stated that NTPC is required

to relinquish the LTA quantum of 130.49 MW as per CERC Connectivity Regulations,

2009.

TCC deliberations

PCKL had stated that installed capacity minus the normative auxiliary consumption

is the power which would be injected into the grid. Financial implication due to

LTA higher than this value would have to be taken care by NTPC only. Whether

beneficiary approval was taken for LTA quantum also needs to be ascertained?

TSTRANSCO had sought clarification that whether similar approach was adopted

by NTPC in other regions. Also, under „Change in Law‟, whether CTU could

consider it favorably. ?

NTPC had stated that LTA application had been made on behalf of beneficiaries

and quantum (overload of 105% and max DC of 101%) was arrived as per the

prevailing Regulations. Liability to pay transmission charges is solely with

beneficiaries. Application was made with certain conditions that payment of

transmission charges would be with beneficiaries. In other regions also similar

approach had been adopted by NTPC and the beneficiaries are directly taking up

with CTU for relinquishment/surrender. LTA had been signed by beneficiaries with

CTU only and NTPC was not a party to it. Beneficiaries were informed at each

step.

CTU had informed that legal opinion in this regard had been taken. Hon‟ble CERC

had come out with Order that even for change in auxiliary consumption it has to be

associated with relinquishment. Secondly on whether overload capacity can be

considered in approved injection, it may be noted that change in Sharing

Regulations is effective from March 2012, while this LTA was granted in October

2011. Relinquishment can be done prospectively and not retrospectively.

KSEBL had stated that they were in agreement with PCKL and the error was made

by NTPC which needs to be amended by NTPC only.

TANGEDCO had also stated that the issue has arisen because of erroneous


application furnished by NTPC. The quantum physically available should be billed

to beneficiaries. Beneficiaries should not be burdened with relinquishment charges.

CTU and NTPC should settle the issue bilaterally.

It was noted that PoC charges are not a function of LTA but LTA has a direct

bearing on Reliability and HVDC charges. Kudgi was the first CG Station in SR

which had come through LTA route. MoP allocation is for 2,400 MW.

All beneficiaries concluded that the additional quantum needs to be relinquished

immediately to avoid future liabilities.

All beneficiaries stated that NTPC should apply for relinquishment. The sharing of

the relinquishment charges could be sorted out based on 92/MP/2015 order.

NTPC had stated that they would apply relinquishment on behalf of the

beneficiaries, however charges, if any, would need to be borne by the beneficiaries.

SRPC deliberations

PCKL stated that they had gone through the detailed procedure notified by

CERC regarding Connectivity Regulations. There is a provision under general in

para 30.2 as reproduced below:

30.2. Any amendment/modification to an existing application, except for reasons

specifically mentioned in the procedure, shall be treated as a fresh

application.

30.3. All costs/expenses/charges associated with the application, including bank

draft, bank guarantee etc. shall be borne by the applicant.

……………..

30.7. All complaints regarding unfair practices, delays, discrimination, lack of

information, supply of wrong information or any other matter related to

Long-term access in ISTS shall be directed to CERC for redressal.

PCKL stated that as can be seen from the above the question of relinquishment

does not arise. Further, CERC could be approached under provision para 30.7

since there was some error in the LTA quantum.

NTPC informed that they had applied for grant of LTA on behalf of the

beneficiaries after obtaining consent from them. LTA was applied on similar

lines for all the projects by NTPC as per the extant provisions of the Regulations

during that time. There had been no error on part of NTPC on the LTA quantum

applied. These LTA agreements have been signed by the beneficiaries directly

with CTU and NTPC is not a party in the Agreement. Beneficiaries were well

aware of the LTA quantum at the time of signing of the Agreement. Since

surrender has been caused by changes in the provisions of CERC Regulations,

the beneficiaries are needed to relinquish the LTA. Benefits of revision would be

for the beneficiaries and NTPC does not have any role / interest. In case of

BRBCL, Railways had given undertaking to bear the relinquishment charges to

CTU and on that basis; CTU has accepted the relinquishment application. NTPC

is only a facilitator for ensuring a combined application to CTU. It would be

better in case SRPC approaches Hon‟ble CERC in this regard.

It was noted that states had also not committed any error in this regard. NTPC on

behalf of the beneficiaries could approach Hon‟ble CERC through Petition to

have clarity on the issue. The plea should be for error and not for relinquishment.


Chairperson, SRPC noted that Hon‟ble CERC generally does not provide

clarifications but they entertain Petitions only. Under provisions of 30.7 of the

Procedure, NTPC could approach Hon‟ble CERC through a petition.

Regional ED, NTPC stated that NTPC could seek clarification from Hon‟ble

CERC, however they would not go through petition. NTPC will not apply for

relinquishment also. This is not the lone case and there were similar issues in

case of Railways, etc and this would affect the stand on those cases also.

CTU clarified that till the quantum is relinquished or some Order is received

from CERC, full LTA quantum would be continued to be billed.

SRPC noted that NTPC would approach Hon‟ble CERC for clarification on the

matter.

URS Accounting

It was noted that the 5th

Amendment had been notified on 12th

April 2017 (wef

01.05.2017) which had clear provisions on power sold beneficiary-wise to market.

This information was not being communicated to SRPC which was leading to

erroneous URS computations. This had commercial implication on fixed charge

reapportionment, approved injection in RTA, fixed charge apportionment in RRAS,

computation of incentive charges, compensation calculation etc. The issue had been

discussed in the Special Meeting held on 29.01.2018.

NTPC/NLC were to furnish consent quantum details beneficiary wise, cleared

quantum details beneficiary wise in PX for the period from 01.05.2017 to

10.12.2017.

Change in URS allocation procedure during ramp violation

Whenever a state has surrendered power (URS) and the same is taken by some other

state, and when that power is returned and in cases of the ramp violations, the

violation quantum was being booked to the URS surrendering beneficiary. It has

been noted that the causer (whichever beneficiary avails the URS) the ramp violation

need to be booked to the causer. Therefore the ramp violation quantum will be

booked to the causer.

It was agreed to implement the same in SR.

PPA wise DC to be furnished by the IPPs

SRPC had observed that in line with CERC Order dated 31.08.2017 in Petition No

28/MP/2016 PPA wise DC has to be furnished by all ISGS. SRLDC vide letter dated

28.05.2018 (Annexure-LXV) had requested all the IPPs in SR to furnish the PPA

wise DC (as per the format attached with the letter).

Pending payments between WR& SR Constituents as on 16.03.2018 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


The matter was further discussed in the CCM (77th

) of WRPC held on 20.4.2018. As

decided in the CCM, one to one Meeting with MPPMCL and SR constituents (Andhra

Pradesh, Karnataka and Tamil Nadu) was held on 9.5.2018 at Jabalpur, to reconcile the

figures.

The status update after 38 CCM is as under:

Karnataka: Karnataka had claimed an amount of Rs. 13,27,208/- towards power

purchase. MPPMCL had claimed Rs.26,38,440/- which was said to be paid by

Karnataka to PTC.

PCKL had informed that the matter was again taken up with MPPMCL on 27.6.2018

and the reply was awaited

Tamil Nadu: Tamil Nadu claimed an amount of Rs. 1,17,17,268/- towards power

purchase. MPPMCL claimed Rs.32,93,935/- which was said to be paid by Tamil Nadu

to PTC. MP had agreed to verify the same within 15 days.

Andhra Pradesh: AP has claimed an amount of Rs. 1,21,76,270/- towards power

purchase for the period 03/97 to 12/2002, out of which, figures related to 2002 &

wheeling charges are reconciled. It was informed by MPPMCL that Andhra Pradesh

Power Co., vide letter no.387 dated 20.08.2010,had claimed net amount payable by MP

after adjustment of wheeling charges as Rs.66.32 Lakhs. MPPMCL had requested

APPCC to verify their claim.

MPPMCL has also submitted details of claims of Rs.5.62 crores as receivable from Andhra

Pradesh for verification of its payments to Chhattisgarh. AP has agreed to provide the same

within 15 days.

Kerala: KSEBL had informed that they would take up the matter for an early meeting

with GRIDCO

Payable amount to PGCIL (WRTS) by SR Constituents (as discussed in 38th

CCM)

Pending payments of NTECL

In the 38th

CCM (29.06.2018), NTECL had expressed concern on pending

payments by beneficiaries and dues were as follows:

Sl. No. Beneficiary

Outstanding dues for

more than 60 days as

on 25.06.2018

1 APPCC Rs. 73.01 Cr.

2 TSPCC Rs.93.43 Cr.

Constituent Amount to be

refunded (Rs.)

Status

AP & TSTRANSCO 17,34,898

Karnataka DISCOM's 18,36,027 Paid

KSEB l0, 17,023 Paid

TNEB 17,40,999

PED 3, 40,692 Paid


3 GESCOM Rs. 17.60 Cr.

4 HESCOM Rs. 69.71Cr.

5 CESCORP Rs. 7.38 Cr.

TANTRANCO vide letter dated 28.12.2017 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.

In the 33rd

SRPC meeting, MD, PCKL had assured that the payment issues with

TANTRANSCO would be resolved before the next SRPC Meeting.

In the 38th

CCM (29.06.2018), PCKL informed that the payment was likely to be

processed in first week of July 2018.

In the TCC Meeting, it was noted that PCKL vide letter dated 31.07.2018 had

cleared the dues of Rs 16,14,28,857 to TNEB towards the monetary compensation

of energy transactions for the period from December 1998 to March 2001 after

deducting wheeling charges receivable by KPTCL from TANTRANSCO.

(TANTRANSCO letter dated 16.08.2018 in this regard is enclosed at Annexure-

LXVI. This gesture of PCKL in settling long pending issue was appreciated.

SRPC deliberations

Director (O), TANTRANSCO thanked PCKL / KPTCL and this forum for the

clearing the payments which were due since long.

Default in payment of outstanding dues by SR beneficiaries

PGCIL vide letter dated 26.07.2018 (refer Annexure-XXIX) had furnished the details of

outstanding dues for more than 60 days as on 06.07.2018 in respect of SR beneficiaries

of POWERGRID are as under:

(Rs in Crores)

Name of the DIC 60-90 days >90 days

Telangana 94.57 ---

AP (AP TRANSCO) 32.12 ---

KSK Mahanadi (AP) 17.88 59.98

Meenakshi Energy Pvt Ltd 9.73 36.01

NTPC Kudgi 28.37 221.45

Simhapuri Energy Ltd 14.55 74.68

Kerala (KSEB) 1.57 ---

Karnataka (HESCOM) 18.72 ---

KSK Mahanadi (TNEB) 7.96 7.35

Coastal Energen (MTOA) 1.11 22.41

PGCIL had requested the concerned utilities to liquidate the outstanding dues on priority

and update the status.

Wheeling Charges from 1.7.2011 onwards

As also noted in the 38th

Meeting of Commercial Sub-Committee held on 29th

June

2018, the transmission charges for natural inter-state lines would be covered under


PoC mechanism from 1.7.2011. Most of the states had filed tariff petitions with

Hon‟ble Commission in respect of natural inter-state lines.

Wheeling charge computations in REA (as per erstwhile SREB decision) comprised

of wheeling charge for usage of natural inter-state lines, wheeling charges for lines

emanating from MAPS (completely embedded in STU) and wheeling charge for

Sirsi- Guttur portion of 400 KV Kaiga-Guttur line. Thus, the wheeling charges

reflected in the monthly REA were discontinued and constituents advised to reconcile

and settle the amounts.

Further, in the 3rd

Amendment to Sharing regulations 2015, it has been stated

“(vii) In case an ISGS is connected only to STU network and the shares of the

beneficiaries of the said station are being delivered through the STU network, such a

line of the STU network shall be considered as an ISTS for the purpose of these

regulations.”

Thus, MAPS evacuation lines are to be considered as ISTS and to be treated

accordingly.

Further, in respect of Sirsi-Guttur line, the procedure approved in the 31st SRPC

Meeting is being adopted.

KSEBL letter dated 03.08.2018 on the above issue is enclosed at Annexure-LXVII.

KPTCL and TNEB had been requested to refund the charges.

Accounting of Drawal of power during complete outage of station including one or

more unit under RSD

The matter had been discussed in the 38th

Meeting of Commercial Sub-Committee held on

29th

June 2018. After discussions, the Sub-Committee had recommended the following

procedure to be implemented.

In case of complete outage of a station (ISGS whose tariff is decided by CERC) then the

exchange of power with ISTS would be accounted in the REA and beneficiaries would

settle it under DSM with the Regional Pool.

Methodology:

Whenever ON BAR DC of the station is zero,

Schedule for the blocks = actual drawal

DC for the blocks = DC OFF BAR+ actual drawal.

Deviation computed for these blocks will be shared by Beneficiaries.

NTPC letter dated 24th

July 2018 is attached as Annexure-LXVIII.

TCC deliberations

NTPC had stated that the deviations in such cases are to be settled under DSM as being

followed in all the other regions. In Petition 42/2005 in case of Talcher, Hon‟ble CERC

had observed that such drawal has to be treated under DSM.

It was noted that in Petition 42/2005, NTPC‟s plea was different. Further no direction

had been passed by the Commission. Hon‟ble Commission had noted that different

Regions are following different methodology and no specific methodology was

advised. SR is following CEA‟s suggested method which NTPC was supporting all

these years.

4th

Amendment of DSM was proposed and NTPC may consider changing its stand

again.


NTPC had stated that a principled approach should be followed. Something different is

being followed in SR and thus uniformity was being sought with the practice in other

regions.

TSTRANSCO had noted that NTPC was silent since 2005, and now since they are

impacted commercially, they were seeking review.

It was agreed to continue with the existing practice as agreed in 38th

CCM, However

this procedure would be reviewed in next CCM.


Compensation revision

NTECL vide mail dated 10.05.2018 had requested for revision of compensation amount

due to revision in landed price and GCV (changes in ECR) of fuel for 2017-18.

TCC deliberations

It was noted that para 5(ii) of the Compensation Procedure approved by Hon‟ble

Commission vide order dated 05.05.2017 states „Generating station shall submit the

requisite data along with compensation calculation to RPC secretariat as prescribed in

Annexure-I to Appendix II for a month by 15th

day of the following month. The data to

be submitted is for the month and reconciled up to the month‟.

TCC noted that variable cost furnished by ISG stations by 15th

April of each year (for

the previous year) would be considered for compensation. Any implication due to

change in ECR (landed price, GCV etc) subsequently would be required to be borne by

the generator / beneficiaries as applicable.


34 IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION

34.1 Automatic Demand Management Schemes

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

have been provided by all constituents. Revised logic at 49.85 Hz, Min DSM violation

for 15 minutes had been implemented by all the States/UT.

34.1.2 Number of incidents satisfying the existing logic is given below:

Month

Present settings as per IEGC

Frequency < 49.85 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 applicable to states

AP Kar Ker TN TS

Feb-18 1 0 0 0 0 0 0

Mar-18 19 3 1 0 0 1 0

Apr-18 22 2 2 0 0 0 0

May-18 107 23 13 0 0 9 1

June-18 34 20 7 0 0 11 2

July-18 28 9 4 1 0 2 1


SRPC noted the above and suggested that ADMS with proper logic should in place at all

times.

34.2 UFR and df/dt reliefs

34.2.1. 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 3575 1427 4399 109 15270

% B/A 100 100 101 122 105 106 104

SCADA monitorable MW C 1650 2318 3575 1399 3790 100 12832

% C/B 59 78 100 98 86 92 84

Average Visible

Relief in Feb 2018 MW D 1592 1750 3232 1255 2779 77 10685

Wrt monitorable % D/C 96 75 90 90 73 77 83

Average Visible

Relief in Mar 2018 MW E 1633 2238 3205 1350 3416 79 11921

Wrt monitorable % E/C 99 97 90 96 90 79 93

Average Visible

Relief in Apr 2018 MW F 1436 1526 3001 1369 3463 86 10881

Wrt monitorable % F/C 87 66 84 98 91 86 85

Average Visible

Relief in May 2018 MW G 1564 1075 2173 1276 3030 91 9209

Wrt monitorable % G/C 95 46 61 91 80 91 72

Average Visible

Relief in June 2018 MW H 1431 1156 1988 1120 2853 79 8626

Wrt monitorable % H/C 87 50 56 80 65 79 64

Average Visible

Relief in July 2018 MW I 1334 1651 2135 1087 2847 83 9136

Wrt monitorable % I/C 81 71 60 78 65 83 68

34.2.2 In earlier Meetings, the following had been noted:

SCADA mapping was to be improved for AP, TS and TN.

Visible relief to be improved for Karnataka and Telangana.

In the special meeting held on 09.07.2018 in respect of pending issues of Karnataka,

it was noted that on account of RE injection which was substantial, the direction of

power flow on some of the identified features had reversed and also in some feeders,

the net flow has been reduced considerably. SRPC vide letter dated 09.07.2018

(Annexure-LXIX) had requested all the states to review the identified feeders for

UFR and if required, to have more number of radial feeders at lower voltage levels.

TCC deliberations

Mapping in AP & TS has to be improved.


TCC had noted the above and requested all the concerned entities to improve the

relief, improve the mapping and look into RE issues leading to reverse/net low

flows.

SRLDC in coordination with states are jointly validating the reverse/ low net flow

(because of RE) and all the states were requested to kindly coordinate and take

corrective action as and when the issues are identified.


34.2.3 NPC had sought views of members on the review of quantum of load shedding and

stages of frequency.Therefore, RPCs were to 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 the 32nd

TCC meeting the following had been noted:

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.


34.2.4 Review of UFR quantum and set points

NPC Secretariat vide letter dated 30.05.2018 (Annexure-LXX) had furnished UFR

quantum to be adopted by SR in the current Grid Environment, which was to be ratified

by NPC. Further NPC secretariat had sought comments on retaining the same set points

(49.2 Hz, 49.0 Hz, 48.8 Hz & 48.6 Hz) or enhancing the set points by 0.2 Hz (49.4 Hz,

49.2 Hz, 49.0 Hz & 48.8 Hz).

KSEBL vide letter dated 20.06.2018 had stated that the existing set points can be

retained. TSTRANSCO vide letter dated 20.06.2018 had suggested that the revision of

set frequencies could be deliberated in the TCC meeting for arriving at consensus on the

issues. APTRANSCO vide letter dated 05.07.2018 had stated that they were agreeable

for increase in settings of 0.2 Hz. In the special meeting held on 09.07.2018, KPTCL

had confirmed that they were agreeable for the increase in setting of 0.2 Hz.

TCC deliberations

TSTRANSCO had stated that existing settings may be retained.

TCC had concluded that existing settings may be retained and the same may be

recommended to NPC.


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

34.3.1 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).

34.3.2 Performance of RGMO is being analyzed in the OCC forum. Summary for Southern

Region (state-wise details are given in Annexure-LXXI) is given in the Table below:

Hydro Thermal TOTAL

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

30.01.2018 (1250 MW loss at Koderma)

41 53 130% 669 159 24% 710 211 30%

23.04.2018 (3090 MW generation loss due to multiple trippings at Kotra (PG)

81 109 135% 1282 380 30% 1363 489 36%

34.3.3 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.

34.3.4 All generators should keep a Margin for RGMO response while declaring DC in all

level ie at full load/partial load operation.

34.3.5 FRC computations were also to be undertaken by the SLDCs in line with approved

methodology of CERC.

34.3.6 In the OCCM, it was pointed out that necessary checks / interlocks needed to be in

place so as to ensure that RGMO margin is available in all the generators under SRLDC

control area. Regulation 5.2(h) of IEGC states, „…………….For the purpose of ensuring

primary response, RLDCs/SLDCs shall not schedule the generating station or unit (s)

thereof beyond ex bus generation corresponding to 100 % of the Installed capacity of

the generating station or unit (s) thereof.‟

34.3.7 SRLDC vide letter dated 07.02.2018 (Annexure-LXXII) had taken up the issue with

IPPs/MPPs.

34.3.8 SRLDC vide letter dated 29.05.2018 (Annexure-LXXIII) had requested all the SLDCs

to furnish the list of all hydro stations and gas stations which are covered under

FGMO/RGMO response along with the status clearly mentioning the CERC Order in

case exemption/extension is received from Commission may be furnished.

SRPC noted the above and suggested the Generators and SRLDC/SLDCs to initiate

necessary action to ensure compliance of IEGC provision.

34.4 Demand Estimation for Operational Purpose (Clause 5.3 of IEGC)

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.


States had been requested to break the state load into sub components like district

wise/substation wise while carrying out the forecasting incorporating weather conditions

etc.

SRPC suggested the states to comply with IEGC provisions.

34.5 Sudden Change in Demand/Frequency Excursion (Clause 5.2 (j) of the IEGC)

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.

SRPC suggested the states/generators to comply with IEGC provisions.

34.6 Arranging of interruptible loads in four groups

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

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

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

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

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

overlapping between different groups of loads.

Existing schemes were not meeting Regulatory requirement fully and further action was

required in this regard. Constituents had been requested to ensure necessary compliance.

SRPC suggested the states to comply with IEGC provisions.

34.7 PSS Tuning

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 (Reports to be analyzed); 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 U 7 & 8 (Report to be

analyzed) 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 U1 (Report to be analyzed) U2 to U5; NCTPS

St-II U1; Kadamparai HEP U1 & U2, Mettur-II (Report to be

analyzed).

TN IPPs

CGS NTPC- Ramagundam U7 & U4 (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 & 2 (Report to be analyzed).

ISTS connected IPPs TPCIL U1 & U2 (U2 Report to be analyzed); Coastal Energen U1;

((Report submitted, to be analyzed), Coastal Energen U1; ((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

KPCL Yeramarus TPP

KAR IPPs JSWEL U4

KSEBL Idukki HEP U1 to U6

TANGEDCO NCTPS St-II U2; Kadamparai HEP U3 & U4

TN IPPs STCMS

CGS NTPC-Ramagundam U1, U2, U3, U5 to U6; 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 Lanco Stage II & III; SGPL-Nellore; SEL U1 to U4; MEL U1 &

U4

SRPC suggested generators to kindly initiate necessary action on the recommendations

finalized in the PSS Meetings.

34.8 Relocation of SPS schemes

A comprehensive report on the SPSs to be shifted to Raichur and SPSs being retained at

Kolar would be furnished by SR-I and SR-II to all the states/UT, SRPC and SRLDC.

States would also communicate the corresponding load to the mapped to the respective

SPSs. The location of new DTPCs would also be coordinated in the exercise.


34.9 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:


SR-II had requested shutdown of IL&FS-Nagipatnam D/C lines for LILO of Neyveli-

Bahoor at Karaikal. IL&FS had suggested alternative method like hot line which

would not require any generation outage at IL&FS. SRPC had requested SR-II to

consider hot line crossing as it would ensure generation continuity at IL&FS and also

ensure Karaikal regional drawal of Puducherry is accounted in the monthly REA and

other commercial account as planned.

On 13.02.2018 and 14.02.2018, there were sudden variations in the DC by Simhadri.

In the 141st OCC meeting, it was noted that sudden intra-day DC variations would be

stopped by ISGS during coal deficit condition. Further, it was noted that clause 6.4.16

of IEGC could be followed in letter and spirit, „……….During fuel shortage

condition, in case of thermal stations, they may specify minimum MW, maximum MW,

MWh capability and declaration of fuel shortage.‟ OCC had noted that even during

supercritical coal stock, fuel shortage was not being declared by some of ISGS

stations. OCC suggested that less than 3 days coal stock need to be declared as fuel

shortage. ISGS need to ensure that in case average DC is less than Ex-bus

(normative) over a day, then DC would need to be maximized during 06:00 to 09:00

hours and also during 18:00 to 21:30 hours, while appropriately reducing DC during

other hours.

CEA vide letter dated 16.02.2018 had informed that a Special Task Force had been

constituted under IGEF Sub-Group-1 for enhancing the flexible operation of existing

coal-fired power plants. The committee has recommended the implementation of

measures for 50 %, 40 % and 25 % minimum load in thermal power stations. The

measures for 50 % minimum load operation requires no investment or minimal

investment (Report is available on CEA website under TRM division). Subsequently,

a meeting was held under the Chairmanship of Member (Thermal) on 08.02.2018. In

this regard and it was decided that 55 % minimum load operation would be

implemented nationwide in first phase. Further, six units, including two units of

NTPC and one unit each from DVC, GSECL, APGENCO, MSPGCL, would be taken

up for 55 % minimum load operation in line with the CERC notification dated

06.04.2016 and 05.05.2017 (IEGC) (4th

amendments). Accordingly SRPC vide letter

dated 23.02.2018 had requested APGENCO to communicate the unit where the 55 %

minimum load operation would be implemented to CE, TRPM Division, CEA, New

Delhi with a copy to SRPC, Bengaluru. In the 144th

OCCM, APTRANSCO informed

that APGENCO had agreed for any of the Rayalaseema unit for flexibility (CEA

letter 16.02.2018). APGENCO would be informing it to CEA.

CEA vide letter dated 10.04.2018 had sought the following data for the study (as

decided in the 3rd

meeting of the Committee)

Historic generation data of renewables (RES) on hourly basis and, if possible, at

15 minutes interval for a period of one year.

Location of installed capacity of all current renewable energy sources and

location of anticipated RES installations by 2022.

The generation data of renewables as received from SRLDC had already been

submitted to CEA. All the states had been requested to kindly furnish location of


installed capacity of all current renewable energy sources and location of anticipated

RES installations by 2022.

CEA vide letter dated 13.04.2018 (Annexure-LXXIV) had informed regarding

registration of all existing and upcoming electricity generating units of the country of

capacity 0.5 MW and above under National Level Data Registry System

The issue of Kudgi DC being more than LGB target was taken up by Chairperson,

SRPC with Chairperson, CERC vide letter dated 28.02.2018 (Annexure-LXXV).

KKNPP had closed both the 400 / 230 kV ICTs from 09.03.2018.

In the OCC Meeting, it was agreed that availability certification of natural inter-state

lines and RPC certified intra-state lines would be carried out by SRPC. The procedure

for submitting the details had been circulated by SRLDC. All the states were to

furnish the element wise outage data with availability computations duly vetted by

SLDC to SRLDC by second of every month as per procedure. The same has to be

verified by SRLDC and furnish to SRPC Secretariat to issue the availability

certificate.

SPS on 400 kV Nellore-NPS line was agreed and implemented on 08.04.2018.

TSTRANSCO vide letter dated 28.02.2018 (Annexure-LXXVI) addressed to

Hon‟ble CERC had taken up the issues of, revision of schedule of inter-state short

term transaction (presently 2 clear days), advance intimation by ISGS units revival

and reduction in processing time for contingency transaction in Energy Exchanges.

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. 35 MW MoP

allocations to Railways (Karnataka) from RGPPL was operational from 25.10.2017.

50 MW & 100 MW to TSTRANSCO & TANTRANSCO was to be made

operational.

Request of SEIL for enhancement of net exportable quantum from 1240 MW to 1254

MW was recommended by the group and noted in the 144th

OCC meeting.

In the OCC meeting, it was reaffirmed (as noted in the 125th

OCC) that for shutdown

of 400 kV bays (for 765 kV bays, NLDC approval was required) code would be

exchanged with SRLDC, though it was not be covered under OCC approval.

KPTCL had been requested to study the high loading of UPCL – Kemar lines and

take up reconfiguration if required.

33rd

TCC: KPTCL informed that after commissioning of 400/220 kV

Arasapadavu S/s, the over loading of 220 kV UPCL-Kemar line would get

relieved.

The issue of frequent tripping of Konaje – Manjeswaram on overload and the set

points was to be settled mutually between KSEBL and KPTCL.

33rd

TCC: KPTCL informed that action has been initiated to change the

relay setting of 110 kV Konaje –Manjeshwar line. Now there are no

trippings.


CEA vide letter dated 04.05.2018 had sought data required for development

Geospatial Energy Map of India which is a part of initiative of Government of India,

Niti Aayog. Data may kindly be arranged to be furnished.

NIWE vide letter dated 09.05.208 had communicated that NIWE is in process of

carrying out Geo-Tagging/Online registry of wind turbines for maintaining a

centralized system of data base. SRPC was requested to revert back with

suggestions/clarifications, if any. SRPC vide letter dated 18.05.2018 had replied to

NIWE in this regard.

It was agreed in the OCC that OCC approval for taking A/R in non-auto mode would

not be taken, however, code would be exchanged (instead of messages) with SRLDC

/ NLDC.

In the OCC meeting, SRLDC had informed that the following practices may be

adopted/continued in real time grid operation for keeping transmission lines in open

condition on account of over voltage with immediate effect:

a. Hand tripping of lines on account of O/V: The existing practice of issuing

real time code from Control Room for hand tripping a line due to over voltage

will be continued during hand tripping.

b. Lines tripping on O/V Protection: Real time code may be issued from Control

Room to continue to keep the line in open condition on account of over voltage

continues to persist in the system. As and when the system voltage becomes

conductive, real time code may be issued for taking the line into service.

c. Lines already tripped due to fault excluding over voltage protection: After

attending the fault, when SLDC/POWERGRID/Other ISTS Licensee is

conveying its readiness, real time code may be issued to take the line into

service without delay. In case due to system constraint or over voltage persisting

in the system, Real time code may be issued from Control Room to continue to

keep the line in open condition on account of over voltage condition. The

remarks column of the respective line in the outage portal may be suitably

modified.

On the observation of NTPC Simhadri, a study on Simhadri-Kalpakka-Gazuwaka

power corridor was carried out by SRPC/SRLDC and discussed with NTPC

Simhadri. It was noted that the system was N-1 compliant. During the outage of one

of the lines of Simhadri-Kalpakka, other two lines loading was expected to go up in

the range of 600 - 650 MW which was well within the thermal loading limits.

Vemagiri (PG)-Nunna (Vijayawada) SPS was disabled as recommended by SRLDC

and approved by OCC.

Mock tests to check the healthiness of KKNPP & Talcher-Kolar SPSs were carried

out on 21.05.2018 and for Raichur -Sholapur SPS on 22.05.2018. Identified issues

were being addressed.

SRLDC had furnished the summary of MVAR testing and the pending observations

were to be closed by the respective entities and it is being reviewed in the OCC.


NLDC letter dated 15.06.2018 (Annexure-LXXVII) had furnished the status report

and expressed concern on multiple tower collapses.

TSSLDC vide letter dated 09.05.2018 (Annexure-LXXVIII) had requested to clarify

whether state utilities and distribution utilities can be addressed to include suitable

clause in the connectivity conditions, that models figuring in the RLMM list are

added to the Grid. SRPC vide letter dated 28.05.2018 (Annexure-LXXIX) had

informed that in the Guidelines issued by MNRE for development of Onshore Wind

Power Projects it had been mandated that no wind turbine model shall be allowed for

installation in the country until it has obtained type and quality certification. MNRE

has stipulated verification of complete certificates of the models etc which needs to

be carried out by the concerned procurement agency.

It was agreed that URS availing on D-1 day will be processed at 2000 hrs after the PX

transactions are cleared.

Power Number for SR states for the year 2018-19 (based on the actual consumption

and Maximum Demand figures during the year 2017-18) are AP: 301, TS: 328, KAR:

355, KER: 129, TN:524, Pudu:13. (Total SR: 1650)

In the 7th

NPC Meeting held on 8th

September 2017, NPC had emphasized the need

for having an accurate All India power system data base for carrying out accurate

power system studies for operational and planning horizons. POSOCO was to prepare

requires formats and circulate to all RPCs and in turn RPCs may obtain data from

their constituents. It was noted that NLDC had furnished the formats to NPC.

Further to the follow up by SRLDC and TSSLDC on DG set requirement to start

auxiliaries at Jurala for black start and reply dated 30.11.2017 of TSGENCO,

TSTRANSCO vide letter dated 17.03.2018 (Annexure-LXXX) had advised

TSGENCO to take up the work in compliance of CEA Regulations.

SRPC vide letter dated 28.06.2018 (Annexure-LXXXI) had enclosed CEA letters

dated 26.06.2018, 20.06.2018 and 01.06.2018 informing about that newly developed

National Power Portal (NPP) which has replaced earlier established Information

Management System (IMS) in CEA. All entities have been requested to enter their

relevant data in NPP (npp.gov.in)

In Petition No. 58/TT/2017 on tariff determination for transmission elements in SR ,

Hon‟ble CERC in its Order dated 05.07.2018 had noted „The Commission during the

hearing of Petition No. 38/TT/2017 filed by the petitioner for approval of

transmission tariff from COD to 31.3.2019 for Assets (10 nos.) of ERSS IX Project in

Eastern Region on 18.1.2018 directed as under:-

“2. Since the petitioner has not submitted proper reply regarding requirement of

regional spares vis a vis their current availability, the Commission directed to

submit a proper reply. The Commission further directed to set up a Committee

consisting of representatives from PGCIL, NLDC and CEA under the Chairmanship

of the Chief(Engineering) of the Commission to assess the requirement of regional

spares including bus reactors, line reactors, ICTs, etc., present availability and

other related issues and submit a comprehensive report on the requirement of spare

bus reactors, line reactors, ICTs and related equipment in different regions of the


country to the Commission by 9.3.2018. The Commission also observed that final

tariff in the matter would be allowed only after consideration of the Report to be

submitted by the Chief (Engineering) of the Commission…….

we direct the Committee to finalize the report and submit the same to the

Commission within two months of this order.”

Based on the tariff orders issued by the SERCs/JERCs for FY 2017-18, the APPC at

the National level has been determined as Rs. 3.53/kWh by CERC in Petition No

4/SM/2018 vide Order dated 21.06.2018.

In Petition No. 198/TT/2017 in the matter of „Determination of transmission tariff

for Asset-I: ±800 kV 3000 MW HVDC Pole-III and LILO of Bishwanath Chariali -

Agra HVDC line for parallel operation of the HVDC station at Alipurduar, Asset-II:

±800 kV 3000 MW HVDC Pole-IV along with Earth electrode station and Earth

Electrode line at Alipurduar and Agra end….‟, Hon‟ble CERC in its Order dated

13.06.2018 had stated, „The AFC allowed in this order shall be applicable from the

date of commercial operation of the transmission system and the billing, collection

and disbursement of the transmission charges shall be governed by the provisions of

CERC (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2010,

as amended from time to time. Further, the transmission charges allowed in this

order shall be subject to adjustment as per Regulation 7(7) of the 2014 Tariff

Regulations.‟

In Petition No. 245/TT/2017 in the matter of „Approval of transmission tariff from

COD i.e. 1.12.2015 to 31.3.2019 for Gooty-Madhugiri 400 kV D/C line and 2x500

MVA transformers along with downstream bays at Madhugiri Sub-station upon

bifurcation of capital cost and hence transmission tariff as per directive of the

Commission vide order dated 18.7.2017 in Petition 54/RP/2016….‟, Hon‟ble CERC

in its Order dated 24.05.2018 had stated, „In response, the petitioner submitted that

KPTCL shall bear the tariff for the Gooty-Madhugiri 400 kV D/C transmission line

(Asset-I) from 1.12.2015 to 24.8.2016 and for 2 x 500 MVA transformers at

Madhugiri Sub-station along-with bays for downstream system (Assets-II, III, IV and

V) from the COD to the commissioning of the downstream assets in terms of order

dated 18.7.2017 in Petition 54/RP/2016. The transmission charges of Asset-I shall

be included in the PoC computation from 25.8.2016 i.e. from the date of

commissioning of 400 kV D/C Madhugiri-Bidadi Transmission Line (TBCB) and for

Assets II, III, IV and V from the date of commissioning of downstream assets.

Accordingly, transmission charges for assets II to V have been withdrawn from PoC

Pool and are being borne by KPTCL till commissioning of downstream assets.‟

In Petition No. 3/TT/2018 in the matter of „Approval of transmission tariff from

COD to 31.3.2019 for “Bunching of Tirunelveli – Edamon section of the Tirunelveli

–Muvathapuza (Cochin) 400 kV quad D/C line initially (and temporarily) at 220 kV

with existing Tirunelveli – Edamon 400 kV twin D/C line (400 kV line charged at

220 kV) under Transmission System associated with Kudankulam Atomic Power

Project”….‟, Hon‟ble CERC in its Order dated 24.05.2018 had stated, „The

Commission directed the staff to request CEA to clarify whether bunching of the

Bunching of Tirunelveli-Edamon section of the Tirunelveli-Muvathapuza (Cochin)

400 kV quad D/C line initially (and temporarily) at 220 kV with existing Tirunelveli-

Edamon 400 kV twin D/C line (400 kV line charged at 220 kV) under Transmission

System associated with Kudankulam Atomic Power Project enhances power flow

between buses and POSCO to validate the reason for increase in 167 MW flow as

claimed by the petitioner within a month..‟


In Review Petition No. 44/RP/2017 in Petition No. 103/MP/2017 along with I.A.

No. 74/2017, Hon‟ble CERC in its Order dated 21.05.2018 had stated, „The Review

Petitioner had raised similar issue in Petition No. 229/RC/2015. The Commission in

its order dated 8.3.2018 in Petition No.229/RC/2015 has dealt with the issue as

under:

“52. CTU has expressed apprehension that if LTA is operationalized in the absence

of LC, the Petitioner would not be able to recover the transmission charges in the

event of default by the DICs. In our view, though there is provision in the BCD

Procedure for opening of LC one month prior to the effective date, LC is not a

condition precedent for operationalization of LTA. If LTA is not operationalized

pending opening of LCs, this will give perverse incentives to the DICs not to open

the LCs to avoid paying the transmission charges. There is therefore a need for

prescribing certain deterrent measures against the defaulting DICs. In our view, a

DIC who has been granted LTA but does not intend to open the LCs, he shall be

debarred from applying for medium term open access and short term open access.

As a result, the DIC in order to avail the medium term and short term open access

will be forced to make payment of LTA charges. Accordingly, we direct that if the

DIC fails to make payment of the transmission charges or open letter of credit at the

end of the month after operationalization of LTA, it shall be denied medium term

open access and short term open access till it makes payment of transmission

charges and open letter of credit.”

Therefore, non-payment of transmission charges and non-opening of LC under the

LTA shall result in the denial of MTOA or STOA.

8. The Commission in the impugned order has decided that opening of LC is not a

condition precedent for operationalization of LTA which has also been reiterated in the

order dated 8.3.2018 in Petition No. 229/RC/2015. The Commission, in the said order

has held also that if a DIC who has been granted LTA but does not intend to open the

LCs, then he shall be debarred from applying for MTOA and STOA. Accordingly, there

is no error apparent in the impugned order...‟

SRPC noted the above and suggested the concerned entities to close the pending issues.

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

IN RESPECT OF LVRT AND OTHER PROVISIONS OF CEA/CERC

REGULATIONS

35.1 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.

35.2 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.

35.3 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.

Identification of optimal location for installing PMUs for LVRT analysis purposes.

Conducting capacity building workshop regarding forecasting and scheduling of RE.

35.5 MNRE had brought out OM dated 01.03.2018 (Annexure-LXXXII) on compliance of

WTG models to applicable CEA Technical standards for Connectivity to the Grid (as

amended from time to time) as stipulated in the MNRE Guidelines/procedure for Revised

List of Models and Manufacturers (RLMM). MS, SRPC vide letter dated 19.04.2018

(Annexure-LXXXIII) addressed to CEA had sought certain clarification wrt MNRE OM

dated 01.03.2018. Further, it was requested that the second amendment to Connectivity

Regulations may please be arranged to be notified at an early date.

35.6 A Meeting to discuss the OM was held at NIWE, Chennai on 23.04.2018 and the minutes

are available at SRPC website. The following was noted:

Status of LVRT testing facility

NIWE had informed that they were in the process of equipping themselves to test all

the provisions of CEA Regulations.

NIWE had informed that at present 21 models from 9 OEMs are having valid

Statement of Compliance (SoC)/Conformity Statement (CS) and figure in the

RLMM list. They are complying with the provisions of CEA Regulations.

A Comprehensive Indian Wind Turbine Certification Scheme was being prepared

and it would cover :

Type Certification

Wind Farm Project Certification

Life Assessment of Wind Turbine – Failure Analysis, Safety Assessment,

Residual Life Assessment, Life Extension & Decommissioning Procedure.

35.7 The forum had strongly felt that there was a need for enabling agency similar to NIWE to

ensure compliance of CEA Regulations for Solar generators since solar targets were

significant and the addition was rapid pace. Based on the recommendations, Chairperson,

SRPC vide letter dated 09.05.2018 (Annexure-LXXXIV) had taken up the issue of

effective implementation of provisions of CEA Regulations (including LVRT / HVRT)

and other security features to agencies like NISE (on similar lines of NIWE).


36 GRID OPERATION

36.1 Salient Achievements

Overarching Agreement was successfully implemented on 28.02.2018 between Kerala

and Karnataka.

Kudgi Unit-I was taken under RSD on 28.02.2018. This was for the first time that any

ISGS unit was taken under RSD. This would pave way for further RE integration.


KGS-1 is operating continuously since 13.05.2016 (770 days as on 22.06.2018). It has

surpassed the earlier record (among NPCIL stations) for longest continuous run of 765

days set by RAPS-5. With this achievement, KGS-1 now stands second in the world

among Pressurized Heavy Water Reactors (PHWR) and fourth among all nuclear

power reactors in terms of continuous operation.

Kaiga GS PLF > 97.77% for the year 2017-18.

NTPC Ramagundam received the Golden Peacock Award on Energy Efficiency

Management in 20th

World Congress on Environment Management and Climate

Change at New Delhi on 06.07.2018.

NTPC officials visited Kothagaudem new station of TSGENCO to gain experience on

best utility practices as the unit was brought up in a compressed time schedule.

SEIL received the Golden Peacock Award for Environment Management for the year

2018 in 20th

World Congress on Environment Management and Climate Change at

New Delhi on 06.07.2018. Renewable energy arm Sembcorp Green Infra has also won

Greentech Gold Award.

Kolar HVDC Station completed two years of „Zero Tripping‟ & „Zero Forced Outage‟

as on 23.06.2106.As per CIGRE Reports, it is a World/Global Record.

Sembcorp (SEIL & SGPL thermal GS in SR) was biggest FDI in India with Installed

capacity of 4000 MW.

Ramagundam stage-I & II, Ramagundam stage-III, Neyveli stage-II and Neyveli TS-I

Expn. had achieved PAFs of > 90% during the year 2017-18.

Ramagundam stage-III and Talcher-II had achieved PLFs of > 85% during the year

2017-18.

On initiative of SRPC secretariat, SR got additional ramp of 262 MW/block from ISG

Stations.

36.2 Grid Highlights during February 2018

SR demand touched all time maximum of 45325 MW.

MVAR testing of SEIL and SGPL completed on 02nd

& 03rd

March 2018.

Revised ADMS settings were adopted by Kerala and Telangana also.

220/132 kV Gachibowli SS in Rangareddy district of existing 2 x 160 + 2 x 100 MVA

was commissioned on 19.02.2018 with augmented capacity of 3 x 160 + 1 x 100

MVA by TSTRANSCO.

220/132 kV Minpur SS in Medak district of existing 2 x 160 + 1 x 100 MVA was

commissioned on 21.02.2018 with augmented capacity of 3 x 160 MVA by

TSTRANSCO.

125 MVAR reactor at 400 kV Mamidipally SS was commissioned on 23.02.2018 by

TSTRANSCO.

4.6 MW of wind (private), 0.004 MW of Solar (state), 0.002 MW of Solar (private)

and 1.3 MW of biomass was commissioned in AP. 36 MW of Solar (private) and 11

MW of other RE was commissioned in TS. 14 MW of Solar (private) and 6 MW of

mini hydro was commissioned in Kerala. 29.4 MW of Wind (private) and 500.875

MW Solar (private) were commissioned in Karnataka.

36.3 Grid Highlights during March 2018

SR Demand touched all time maximum demand of 47210 MW


SR Consumption touched 1080 MUs.

LILO of 220 kV ADR Palem – Bobbli D/C line from loc. No.43 to proposed 400 kV

SS to Garividi in Vizianagaram district of 2 Ckm was commissioned on 15.03.2018

by APTRANSCO.

220 kV D/C line from 400 kV SS Gani to 220 kV SS Somayajulapalli in Kurnool

district of 34.6 Ckm was commissioned on 31.03.2018 by APTRANSCO.

220 kV SS Gundala in Krishna Dist of Existing 3 x 50 MVA was commissioned on

25.03.2018 by APTRANSCO with augmented capacity of 1 x 80 + 2 x 50 MVA.

220 kV D/C line with Moose conductor from 220/132 kV Narketpally SS to Udaya

Samudram 220/11 kV SS in Nalgonda dist of 18.18 Ckm was commissioned on

31.03.2018 by TSTRANSCO.

220 kV Chandrayagutta in Rangareddy Dist of existing 2 x 160 + 2 x 100 MVA was

commissioned on 20.03.2018 by TSTRANSCO with augmented capacity of 3 x 160 +

1 x 100 MVA.

Nelamangala-Yelahanka (39.006 Km) OPGW Fibre communication link of Central

Sector was put into service for commercial operation w.e.f 28.03.2018 by SR-II,

PGCIL.

Hoody-Yelahanka LILO point of Nelamangala – Hoody, Hoody-HSR (KPTCL),

Peenya-NRS-Hebbal (KPTCL), Hoody-HAL (KPTCL), LILO of Pondy –

Sriperumbadur to SV Chatram (TANTRANSCO), LILO of Neyveli TS-II – Neyveli

TS-I to NNTPS, Salem(PG) – Salem (TNEB) and Sriperumbadur (PG) to

Sriperumbadur (TNEB) OPGW Fibre links (98.484 Km) were put under commercial

operation w.e.f 28.03.2018 by SR-II, PGCIL.

1x 125 MVAR, 400 kV Bus Reactor along with its associated bays and equipments at

Tumkur (Pavagada) pooling station were put under commercial operation w.e.f 00:00

hrs of 31st March 2018 by SR-II, PGCIL.

1 x 500 MVA 400/230 kV ICT along with associated bays and equipment at

Tirunelveli 400/230 kV substation were put under Commercial Operation w.e.f 00:00

hrs of 31st

March 2018 by SR-II, PGCIL.

LILO of 400 kV D/C Bellary-Tumkur (Vasantnarsapur) (Quad Moose) TL at Tumkur

(Pavagada) pooling station along with associated bays and equipments were put under

Commercial Operation w.e.f 00:00 hrs of 31st March 2018 by SR-II, PGCIL.

1 x 500 MVA 400/230 kV ICT along with associated bays and equipment at

Karaikudi 400/230 kV substation were put under Commercial Operation w.e.f 00:00

hrs of 2nd

April 2018 by SR-II, PGCIL.

1 x 500 MVA 400/230 kV ICT along with associated bays and equipment at Arasur

400/230 kV substation were put under Commercial Operation w.e.f 00:00 hrs of 31st

March 2018 by SR-II, PGCIL.

136.4 MW of wind (private) and 3 MW of Solar (private) was commissioned in AP.

27.5 MW of Solar (private) was commissioned in TS. 190.175 MW of Wind

(private) was commissioned in TN. 203.5 MW of Wind (private) and 909.3 MW

Solar (private) were commissioned in Karnataka.


36.4 Grid Highlights during April 2018

220 kV SS Parchur in Prakasam district of existing 3 x 100 MVA was commissioned

on 22.04.2018 by APTRANSCO with augmented capacity of 2 x 100 + 1 x 160

MVA.

220 kV D/C line from 400 kV Asupaka SS to 220 kV Aswaraopet SS in Khammam

dist of 40.282 Ckm was commissioned on 28.04.2018 by TSTRANSCO.

220/132 kV SS Aswaraopet (Upgradation of existing 132/33kV SS Aswaraopet) in

Khammam district with 100 MVA capacity was commissioned on 28.04.2018 by

TSTRANSCO.

220 kV Mandamari SS in Mancherial Dist of existing 2 x 100 MVA was

commissioned on 06.04.2018 by TSTRANSCO with augmented capacity of 3 x 100

MVA.

220 kV Chandrayanagutta SS in Rangareddy Dist of existing 3 x 160 + 1 x 100 MVA

was commissioned on 09.04.2018 by TSTRANSCO with augmented capacity of 4 x

160 MVA.

1 x 500 MVA, 400/220 kV ICT along with bays and equipment at Kozhikode

400/220 kV Substation were put under commercial operation w.e.f 00:00 hrs of 3rd

April 2018 by SR-II, PGCIL.

1 x 500 MVA transformer at 400/220 kV Narendra substation (replacement of

existing 2nd

1 x 315 MVA 400/220 kV transformer) was put under commercial

operation w.e.f 00:00 hrs of 16th

April 2018 by SR-II, PGCIL. It was informed that

the replaced 1 x 315 MVA transformer shall be utilized as a regional spare.

18 MW of wind (private) and 61.896 MW of Solar (private) was commissioned in

AP. 2.5 MW of Solar (private) was commissioned in TS. 22.5 MW of Wind (private)

was commissioned in TN. 4.5 MW of wind (private) and 58 MW of Solar (private),

was commissioned in Karnataka.

36.5 Grid Highlights during May 2018

187 MU of Wind generation recorded on 10.06.2018 in SR.

220 kV S/C line from Chakrayapeta to LILO point of 33/220 kV pooling SS in

Animala of 25.662 Ckm was commissioned on 19.05.2018 by APTRANSCO.

220 kV D/C line from Chakrayapeta to Talamanchipatnam in Kadapa dist of 174.396

Ckm was commissioned on 19.05.2018 by APTRANSCO.

220 kV D/C line for making LILO of existing one circuit of 220 kV Vemagiri to

Undiline at proposed 220/132/33 kV SS Duvva in West Godavari district of 0.64 Ckm

was commissioned on 27.05.2018 by APTRANSCO.

220/132/33 kV SS Duvva in West Godavari district with 116 MVA capacity was

commissioned on 27.05.2018 by APTRANSCO.

220/132/33 kV SS at Chakrayapeta in Kadapa district with 100 MVA capacity was


220 kV SS Tekkali in Srikakulam district of existing 2x100 MVA was commissioned

on 16.05.2018 by APTRANSCO with augmented capacity of 3x100MVA.

400 kV Gajwel to Ramadugu I 129.529 Ckm was commissioned on 06.05.2018 by

TSTRANSCO.

400 kV Ramadugu to STPP I 67.909 Ckm was commissioned on 06.05.2018 by

TSTRANSCO.


400 kV KTS – VII to Julurupadu I 39.08 Ckm was commissioned on 19.05.2018 by

TSTRANSCO.

400 kV KTS – VII to Julurupadu II 39.08 Ckm was commissioned on 19.05.2018 by

TSTRANSCO

400/220 kV Gajwel SS in Siddipet district of existing 3 x 315 MVA was

commissioned on 03.05.2018 by TSTRANSCO with augmented capacity of 3 x 315 +

1 x 500 MVA.

220/132 kV SS Gunrock in Hyderabad District of existing 2 x 160 MVA was

commissioned on 24.05.2018 by TSTRANSCO with augmented capacity of 3 x 160

MVA.

220/132 kV LI SS Huzurabad in Karimnagar Dist of PTR I 100 MVA capacity was

commissioned on 14.05.2018 by TSTRANSCO.

LILO of 400 kV S/C Nelamangala – Hoody Transmission Line, 2 x 500 MVA,

400/230 kV ICTs at new 400/220kV GIS Substation at Yelahanka with 1 x 63 MVAR

420 kV Bus Reactor, along with associated bays & equipments were put on COD

w.e.f 00:00 hrs of 1st April 2018 by SR-II.

2 x 400 kV D/C (Quad) Tirunelveli (Tuticorin II) PS - Tuticorin PS, 2 x 500 MVA,

400/230 kV transformers, 2 x 125 MVAR 400kV Bus Reactors along with associated

bays & equipment were put under Commercial Operation w.e.f 00:00 hrs of 10th

June

2018 by SR II.

12 MW of wind(private) and 4.004 MW of Solar (private) was commissioned in AP.

06 MW of solar (private) was commissioned in TS. 1.25 MW of solar (private) was

commissioned in Kerala. 50 MW of Solar (private) was commissioned in Karnataka.

36.6 Grid Highlights during June 2018

17 MW of wind (private) & 251 MW of Solar (private) was commissioned in Andhra

Pradesh, 27 MW of wind (private) was commissioned in Telangana, 90 MW of solar

(private) was commissioned in Karnataka, 8.849 MW of solar (private) was

commissioned in Kerala and 37.375 MW of wind (private) was commissioned in

Tamil Nadu.

Highest ever Wind generation of 223 MU recorded on 27.06.2018 in SR.

220 kV D/C line for making LILO of existing 220kV Nellore – Ongole line at

proposed 220/132 kV SS Racharlapadu in Nellore district of 16 Ckm was


220 kV D/C line for making LILO of 132 kV Podili-Nellore to proposed 220/132 kV

SS Kandukur in Prakassam district of 107.4 Ckm was commissioned on 30.06.2018 by

APTRANSCO.

220/132/33 kV SS Racharlapadu I in Nellore district with 100 MVA capacity was


220/132/33 kV SS Kandukur I in Prakasam district with 100 MVA capacity was


400/220 kV SS Kalikiri II in Chittoor district with 315 MVA capacity was

commissioned on 18.06.2018 by APTRANSCO

220 kV SS Brandix (Idle charge) in Visag district of Existing 2 x 100 MVA was

commissioned on 28.06.2018 by APTRANSCO with augmented capacity of 3 x 100

MVA.


400 kV Ghani II SS in Kurnool district of was commissioned on 28.06.2018 by

APTRANSCO with capacity of 125 MVAR.

220 kV Twin Moose DC/SC line from 400 kV Budidampadu SS (PGCIL) 500 MVA

PTR bay to 220 kV Budidampadu SS I 0.5 Ckm was commissioned on 14.06.2018 by

TSTRANSCO.

400 kV Gajwel to Narsapur II 48.6 Ckm was commissioned on 12.06.2018 by

TSTRANSCO

1 x 500 MVA, 400/230 kV ICTs along with associated bays and equipments at

400/230 kV Pondicherry Substation were put under Commercial Operation w.e.f 00:00

hrs of 22nd

June 2018 by SR-II.

1 no. 400/220 kV 500 MVA ICT III along with associated bays and equipment at

Khammam S/s & 1 no. 400/220 kV 500 MVA ICT III along with associated bays and

equipment at Warangal S/s were put under Commercial Operation w.e.f 00:00 hrs of

28th

June 2018 by SR-I.

1 no. 400/220 kV 500 MVA ICT III along with associated bays and equipment at

Gooty S/s was put under Commercial Operation w.e.f 00:00 hrs of 1st July 2018 by

SR-I.

36.7 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 February

2018 to July 2018:

Description

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala

Tamil

Nadu Pudu

Southern

Region

February 2018

Highest 41.59 36.27 27.02 38.89 34.82 41.18 27.24

Date (Day) 02.02.2018

(Friday)

08.02.2018

(Thursday)

09.02.2018

(Friday)

05.02.2018

(Monday)

05.02.2018

(Monday)

05.02.2018

(Monday)

05.02.2018

(Monday)

Lowest 31.30 20.09 13.28 29.59 15.52 21.14 12.48

Date (Day) 10.02.2018

(Saturday)

25.02.2018

(Sunday)

25.02.2018

(Sunday)

24.02.2018

(Saturday)

25.02.2018

(Sunday)

11.02.2018

(Sunday)

25.02.2018

(Sunday)

Average 34.69 29.57 18.99 33.19 27.51 33.74 20.53

March 2018

Highest 35.05 45.69 29.40 37.66 30.14 42.13 23.39

Date (Day) 03.03.2018

(Saturday)

17.03.2018

(Saturday)

16.03.2018

(Friday)

31.03.2018

(Saturday)

19.03.2018

(Monday)

17.03.2018

(Saturday)

17.03.2018

(Saturday)

Lowest 22.24 11.38 11.48 25.04 9.27 19.41 9.17

Date (Day) 18.03.2018

(Sunday)

31.03.2018

(Saturday)

29.03.2018

(Thursday)

13.03.2018

(Tuesday)

25.03.2018

(Sunday)

28.03.2018

(Wednesday)

25.03.2018

(Sunday)

Average 28.40 19.99 17.27 30.56 21.29 29.40 15.14

April 2018

Highest 35.41 52.13 29.42 36.20 22.43 44.67 19.61

Date (Day) 24.04.2018

(Tuesday)

06.04.2018

(Friday)

22.04.2018

(Sunday)

04.04.2018

(Wednesday)

30.04.2018

(Monday)

25.04.2018

(Wednesday)

02.04.2018

(Monday)

Lowest 17.49 9.37 10.83 25.04 8.66 18.42 7.09

Date (Day) 29.04.2018

(Sunday)

15.04.2018

(Sunday)

14.04.2018

(Saturday)

13.04.2018

(Friday)

14.04.2018

(Saturday)

14.04.2018

(Saturday)

29.04.2018

(Sunday)

Average 25.19 21.22 17.99 30.32 14.52 27.55 13.67

May 2018

Highest 34.96 58.06 42.93 43.97 26.41 35.73 28.58

Date (Day) 01.05.2018

(Tuesday)

03.05.2018

(Thursday)

03.05.2018

(Thursday)

04.05.2018

(Friday)

29.05.2018

(Tuesday)

27.05.2018

(Sunday)

04.05.2018

(Friday)


Lowest 18.91 15.48 12.24 17.07 8.12 14.63 7.68

Date (Day) 05.05.2018

(Saturday)

24.05.2018

(Thursday)

01.05.2018

(Tuesday)

13.05.2018

(Sunday)

13.05.2018

(Sunday)

30.05.2018

(Wednesday)

06.05.2018

(Sunday)

Average 26.82 22.84 25.11 31.64 17.82 25.64 15.85

June 2018

Highest 29.13 31.43 37.00 48.05 26.35 44.26 25.62

Date (Day) 21.06.2018

(Thursday)

23.06.2018

(Saturday)

04.06.2018

(Monday)

12.06.2018

(Tuesday)

11.06.2018

(Monday)

15.06.2018

(Friday)

04.06.2018

(Monday)

Lowest 15.29 15.10 17.91 27.86 9.21 14.53 9.01

Date (Day) 12.06.2018

(Tuesday)

10.06.2018

(Sunday)

16.06.2018

(Saturday)

02.06.2018

(Saturday)

03.06.2018

(Sunday)

24.06.2018

(Sunday)

03.06.2018

(Sunday)

Average 21.92 23.02 25.68 36.23 17.65 24.43 16.48

July 2018

Highest 29.52 31.68 34.17 50.72 29.59 57.85 24.64

Date (Day) 29.07.2018

(Sunday)

18.07.2018

(Wednesday)

13.07.2018

(Friday)

17.07.2018

(Tuesday)

03.07.2018

(Tuesday)

16.07.2018

(Monday)

13.07.2018

(Friday)

Lowest 15.04 16.86 20.74 30.56 9.66 15.26 10.74

Date (Day) 11.07.2018

(Wednesday)

29.07.2018

(Sunday)

07.07.2018

(Saturday)

08.07.2018

(Sunday)

22.07.2018

(Sunday)

21.07.2018

(Saturday)

29.07.2018

(Sunday)

Average 20.74 24.78 26.58 37.93 19.18 25.29 18.10

Note: Highest & lowest figures for the month have been computed based on the daily

values.

36.8 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.

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

February 2018 0.00 0.00 9.68 53.15 27.00 10.17 0.00 80.15 49.98

March 2018 0.00 0.00 12.99 55.23 23.95 7.82 0.01 79.18 49.97

April 2018 0.00 0.02 12.74 53.66 25.72 7.86 0.00 79.37 49.97

May 2018 0.00 0.22 22.29 48.41 21.44 7.64 0.00 69.85 49.95

June 2018 0.00 0.13 11.71 46.60 30.07 11.46 0.03 76.66 49.98

July 2018 0.00 0.09 10.33 49.16 29.12 11.30 0.00 78.28 49.98

During the period under review, caution / violation messages (Annexure-LXXXV)

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.

In the OCC meetings, SRPC & SRLDC had pointed out that sustained violation of

reversal of sign was to be avoided for compliance of IEGC /DSM Regulations.

Regulation 6.4.6 of IEGC states „…………… Every regional entity shall ensure

reversal of sign of deviation from schedule at least once after every twelve time

blocks.‟ Regulation 7(10) of DSM Regulations states, „In the event of sustained

deviation from schedule in one direction (positive or negative) by any regional entity,

such regional entity (buyer or seller) shall have to make sign of their deviation from

schedule changed, at least once, after every 12 time blocks.‟


37 CERTIFICATION OF NON-ISTS LINE CARRYING INTER-STATE POWER FOR

THE YEAR 2018-19

As per provisions of CERC Regulations and as per the methodology approved in the 31st

Meeting of SRPC, SRPC Secretariat vide letter dated 20th

March 2018 (Annexure-LXXXVI)

has certified the non-ISTS lines carrying inter-state power for the year 2018-19. The studies

were done in close consultation with SRLDC.

TCC noted the above.

APTRANSCO vide letter dated 31.07.2018 (Annexure-LXXXVII) had stated that non-ISTS

lines carrying inter-state power of more than 50% of total power transmitted as per load flow

studies are only certified by SRPC for including in POC pool for recovery of YTC of the

lines. As per CERC (Sharing of Inter-state Transmission Charges and Losses) (3rd

amendment) Regulations, 2015, the cutoff 50 % has been removed. Hence, it was requested

to remove the cutoff percentage for certification for certifying of non-ISTS lines carrying

ISTS power.

TCC deliberations

APTRANSCO had stated that this would affect all the states and AP was affected

severely due to it being the entry point into SR due to geographical position. For any

new connection to ISTS, POC charges for AP increases. For the ISTS power of other

states, APTRANSCO should get to recover the associated charges through POC

mechanism. Many a times CTU is stating interconnectivity to STU for system

strengthening but the same is impacting the POC charges subsequently.

PCKL had pointed out that the landing points of 765 kV line in Karnataka also

contribute significantly towards POC charges for Karnataka.

TANGEDCO had endorsed the views of APTRANSCO and stated that the state network

is being utilized by the RE generators. The cutoff needs to be reduced from 50%.

It was noted that STU lines get constructed for evacuation of state power. When these

lines are connected to ISTS, there would be incidental flows as per laws of physics. One

way to view the matter would be to consider whether the other states would be able to

receive their power through ISTS lines if the state lines are taken out from studies.

Considering these issues it makes sense to put some threshold (say 50%) to recover the

YTC of intra-state lines through POC. If a state over designs its system, then the other

DICs may be burdened, in case no threshold is considered.

TSTRANSCO had observed that 50 % was fixed as per the recommendations of the CC

Meeting and approval of the TCC/SRPC. Most likely 50% was being considered in

other regions as cutoff and the same should continue in SR.

It was agreed that this issue would be discussed further in a separate Meeting.

SRPC noted the above and suggested that the issue could be further deliberated in a

separate meeting.


38 EFFECT ON POC CHARGES ON ACCOUNT OF SCHEDULING WIND AND

SOLAR STATIONS BY RLDC

APTRANSCO vide letter dated 30.07.2018 (Annexure-LXXXVIII) had requested

deliberation on the effect on POC charges for any state in case RLDC does the scheduling of

RE power as per IEGC.

TCC deliberations

It was noted that there would be no effect on PoC charges in case the scheduling is taken

over by RLDC for RE generators.


39 MEMBERSHIP OF TRADER IN SRPC FOR THE YEAR 2018-19

CEA, New Delhi vide letter dated 9th

April 2018 (Annexure-LXXXIX) had communicated

that M/s. Mittal Processors Pvt. Ltd. would be the Member (Trader) in SRPC for the year

2018-19.

SRPC noted the above

40 REIMBURSEMENT OF SRPC EXPENDITURE

Statement showing net amount payable by Member Utilities of SRPC for the year 2018 -19,

after adjustment of surplus/deficit for the previous period is furnished in Annexure-XC.

Members were kindly requested to ensure payment, wherever due.

41 OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE

A special meeting was held at SLDC, KSEBL, Kalamassery on 13.04.2018 (MOM enclosed

at Annexure-XCI). In the 143rd

OCC meeting, the forum had concluded that the performance

of hydro stations cannot be assessed by means of any standard formats. In view of this, OCC

had unanimously agreed to drop the matter regarding monthly performance from the OCC

agenda since this issue had already been deliberated at length in various forums also.


42 RSD & TECHNICAL MINIMUM

42.1 KSEBL and TSTRANSCO had raised certain issues in respect of scheduling during RSD of

one of the units at Kudgi and these issues were discussed in detail in the OCC and CC

meetings. NLDC vide letter dated 06.04.2018 (Annexure-XCII) had proposed discussion on

RSD procedure in each of the RPC as noted in the approved RSD procedure. In the OCC

meeting, it was noted that NLDC had confirmed that the procedure being followed was in

line with the Regulations / Procedure. However, the concern of the states (TS/Kerala) would

be communicated to Hon‟ble CERC as they have sought comments on the TM / RSD

procedure and Compensation Mechanism. The states had also been requested to furnish their

views to NLDC on TM / RSD Procedure. SRPC vide letter dated 16.04.2018 (Annexure-

XCIII) had furnished its comments to Hon‟ble CERC. Subsequently, SRPC vide letter dated


05.07.2018 (Annexure-XCIV) had taken up the concern of SR states on RSD procedure

with Director (MO), POSOCO.

42.2 In the OCCM, NTPC, Kudgi had informed that the requirement of 35 hours to bring back the

Kudgi super critical unit from cold start under RSD would be taken up through NTPC

Corporate with NLDC / CERC.

42.3 The following was noted in the TCC Meeting:

TSTRANSCO had pointed out RSD decision is taken based on surrender but share

allocation on the requisitions and recall provision of 8 hours (8 hours of continuous

schedule) is not being factored in present methodology. The Procedure implementation

needs to be reviewed. This is a Procedure prepared by NLDC in consultation with

constituents and approved by CERC. The Commission could be apprised of the issue by

NLDC and the decision would be complied.

It was noted during periods when Karnataka is not requiring power they are scheduled

power as per the Onbar DC.

KSEBL had stated that RSD of Kudgi is getting reflected as a forced surrender by

Kerala. Karnataka when putting machines in RSD should be permitted only the share

available with the running unit after allocating the full share requested by other

constituents. Scheduling by cherry picking by availing the entire share when units are

put in RSD by one constituent should not be permitted.

TSTRANSCO and KSEBL had stated that NLDC needs to appropriately consider their

inputs in the feedback to Hon'ble CERC.

NLDC had stated that they would consider the remarks of TS and KSEBL. However it

requested TS and KESBL to kindly take up the issue independently also.

NLDC had once again clarified that the same procedure which is existing is being

followed in all the regions and is line with the procedure / regulations.


43 FREQUENT REVISION OF OUAGE PLAN BY ISG STATIONS

NTPC/NTECL had revised the annual outage plan for the FY 2018-19 in the month of April

2018 from the plan originally submitted. SRPC vide letter dated 16.04.2018 (Annexure-

XCV) had expressed concern that frequent changes in the annual outage plan have been well

deliberated in the earlier OCC /TCC meetings. Based on the outage plan furnished by the

generators and the MoP target, LGBR and the outage plan are prepared. These inputs are also

utilized by the states for their regulatory compliance, purchase planning etc. The need for

adhering to the outage plan was also highlighted.


44 COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF

RENEWABLE ENERGY SOURCES

44.1 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

31.07.2018 Mapped I/C

Remarks

AP Wind: 3908/4009 MW (97%)

Solar: 2033/2518 MW (81%)

Total: 5941/6527MW (91%)

Pending SCADA availability was for

RE connected distribution level and

for which action had been taken for

compliance.

TS Wind: 121.8/121.8 MW (100%)

Solar: 3075/3319 MW (93%)

Total: 3203/3448 MW (93%)

Action for balance SCADA

availability at 33 kV and below was

being followed up and notices had

been issued.

KA Wind: 4751/4795 MW (99%)

Solar: 4602/5093 MW (90%)

Total: 9353/9888 MW (94.59%)

KE Wind: 16/59.3 MW (27%)

Solar: 93/111 MW (83%)

Total: 109/170.3 MW (64%)

TN Wind: 8090/8255 MW (98%)

Solar: 648/2278 MW (28%)

Total: 8738/10533 MW (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 July 2018.

44.2 A Meeting regarding “Furnishing Real Time/Daily Renewable Energy Generation Data”

was held at Jaipur, Rajasthan on 04.05.2018 under the Chairmanship of Member

(Planning), CEA (MOM is available at Annexure-XCVI). In the meeting, it was decided

that the status of the pooling stations having data communication would be ascertained and

the percentage of availability of communication link/system should be monitored and

reported on a weekly basis. States had agreed to follow the same.

SRPC noted the above. States were requested to furnish the information in a time bound

manner.

44.3 In respect of REMC project (SRLDC, AP, Karnataka & TN) it had been noted that

sanction of GoI had been received during September 2017 and implementation schedule

was of 14 months. The effective date of contract is 29.01.2018 (Awarded to M/s

Chemtrols/OSI (JV), date of Award is 29.09.2017) with completion schedule of 14 months


(29.03.2019). The following is the updated status (as on 05.07.2018):

a) Site survey of Control Centres is completed and the Control Centre buildings of

KPTCL & APTRANSCO are expected to be ready by October 18.

b) Database & display building is expected to be completed by August 18 for the

stations envisaged under the project (TN-140, AP-48, KAR-78 & SRLDC-5)

c) ICCP testing successfully completed with SCADA systems of RLDC & SLDCs for

the integration of RE stations reporting to existing SCADA systems.

d) Vendor is finalized for forecasting & scheduling services.

e) Engineering activities are in progress and expected to be completed by August 18.

f) Supplies (SCADA hardware & Software and Video projection displays) are expected

to resume from end October 18 and total commissioning is expected by Jan 19.

g) Training programs on RE introduction, System administration, system software &

Historian & Application software are completed and course on RE forecasting &

scheduling is proposed in August 18.


45 SCHEDULING OF ANANTHAPURAMU ULTRA MEGA SOLAR PARK /

RAMAGUNDAM SOLAR PROJECT

45.1 In the Meeting held on 15.06.2018, it was agreed that the complete share of 10 MW of

Ramagundam Solar Power project would be availed by Telangana (including 6 MW

presently allocated to AP) along-with 10 MW from unallocated power of coal based NTPC

stations of SR (MoM available on SRPC website). The same was implemented from

01.07.2018 after the concurrence from CEA.

45.2 In the special meetings held on 02.05.2018 and 08.05.2018, it was agreed that scheduling of

Ananthapuramu Ultra Mega Solar Park (1500 MW) would be carried out by SRLDC.

SRPC vide letter dated 10.05.2018 (Annexure-XCVII) had communicated the activities of

the SPDs and SPPD.

45.3 Further, to have clarity on issues, SRPC vide letter dated 25.05.2018 (Annexure-XCVIII)

had communicated the feedback on Procedure for implementation of the Framework on

forecasting, scheduling and in balance handling for Renewable Energy (RE) generating

stations including power parks based on wind and solar at inter-state level with CERC.

45.4 NTPC vide letter dated 09.07.2018 (Annexure-XCIX) had raised certain issues on metering

and scheduling of Ananthapuramu Ultra Mega Solar Park. SRPC Secretariat vide letter

dated 30.07.2018 (Annexure-C) had replied to the queries raised by NTPC.


It was agreed that SPDs would complete all the requirements as communicated by

SRLDC.

APSPCL had informed that Meters are to be replaced with compatible Meters by the

SPDs. SPDs till now are not aware of the deviation charges/financial implications and

some trial period may be required.

It was noted that similar RE framework was already implemented in AP. APTRANSCO


informed that from 01.07.2018 accounts will be issued within one week.

Mock exercise would be taken up from 1st September to 10

th September 2018.

From 11th

September 2018, scheduling would be carried out by SRLDC. Entire

compliance would be ensured by SPDs.

NTPC committed for the mock exercise and also scheduling by SRLDC as per the above

time schedule.

45.6 The following was noted in the SRPC meeting:

MD, APSPCL informed that on 23.08.2018, a meeting with Developers was planned at

Bengaluru and issues would be resolved. He assured that the time lines finalized in this

Meeting would be adhered.

SRPC noted that the scheduling of Ananthapuramu Ultra Mega Solar Park by SRLDC

would be undertaken with commercial settlement and as per RE procedure from

11.09.2018.

46 KARAIKAL DRAWAL

Karaikal would be drawing power through LILO of Neyveli-Bahour which is a PGCIL ISTS

line. SR-II had been kindly requested to update on the readiness along with the proposal ( hot

line crossing) for LILO works, especially in view of the fact that line crossing of generation

evacuation line (ILFS) is involved.

SR-II confirmed that the crossing would be taken using hot line crossing techniques.

47 GRID STUDY COMMITTEE (GSC) MEETINGS ON PACKAGE-A & PACKAGE-B

MoP (GoI) has constituted a "Task force on Power System Analysis under Contingencies" in

December 2012 as a follow up of the recommendations of Enquiry Committee under

Chairperson, CEA on Grid Disturbances of 2012 in Indian Grid.

The Task Force broadly made recommendations regarding analysis of the network behaviour

under normal as well as contingency scenarios, review of the philosophy of operation of

protection relays, review of islanding schemes and technological options to improve the

performance of the grid. To ensure secure and reliable operation of the National Grid and also

for optimizing the transfer of power through the Inter-regional lines/corridors, it was also

found necessary to review the criteria related to Transfer Capability of these lines/corridors

through a consultant.

With the above objectives, MOP directed POWERGRID to appoint Consultants to conduct the

study/ analysis to ensure secure and reliable operation of the National Grid. MOP also directed

that a Grid Study Committee comprising of members from CEA, CTU, STUs, POSOCO & other

members as required, would be constituted to facilitate the consultant‟s study/analysis.


Accordingly, the Terms of Reference (TOR) were prepared by POWERGRID in consultation

with CEA and POSOCO. The works were undertaken in two separate packages:

Package-A: To review the status of implementation of recommendation of Enquiry Committee

on Grid Disturbance and Protection Audit: Awarded to M/s Tractebel Engineering, Romania.

The consultancy assignment for Package A comprised two Tasks as follows:

Task - I: To study and review the status of implementation of recommendations of the

Enquiry Committee.

Task - II: To conduct on site Protection audit check of the works already carried out, for

10% (76 nos.) of 762 Substations across the country after grid failure of July 2012.

Package-B: To review transmission system transfer capability and review of operational and

long term planning: Awarded to M/s Powertech Lab Inc. (PLI), Canada. The consultancy

assignment for Package-B comprised six Tasks as follows:

Task-I: Examination and Recommendation of Methodology for Optimum Calculation of

Transfer Capability (TIC/ATC/TRM) in the Planning and the Operational Horizons.

Task -II: Calculation of Transfer Capability (TIC/ ATC/TRM) for entire country.

Task-III: Guidelines for developing and implementing System Protection Scheme (SPS)

and Islanding schemes and review existing schemes.

Task-IV: Operational Planning and Long-term planning for secure and efficient operation

of the grid.

Task-V: Suitable suggestions in the Regulatory framework to ensure Secure and efficient

grid operation.

Task-VI: To review the tuning of all Power Electronic Devices (including FACTS and

HVDC) and suggest retuning of setting of these devices, as per report of Task Force.

The Grid Study Committee (GSC), which was constituted to facilitate the consultant's study/

analysis, had so far held five meetings (GSC-1 on 22.05.2015; GSC-2 on 16.07.2015; GSC-3 on

18.11.2015).

GSC in the 4th

Meeting held on 16.01.2018 (its minutes issued vide NPC letter dated 01.03.2018

were circulated to SR-Constituents along with the minutes of PCSC-72 meeting issued vide

SRPC letter dated 13.04.2018), accepted the following reports:

Reports of the Consultant M/s Tractebel Engineering on Task I & II under Package A.

Reports of the Consultant M/s Powertech Labs Inc. on Task I, II & III under Package B.

GSC in the 5th Meeting held on 18.06.2018 (minutes issued vide NPC letter dated 26.06.2018

were circulated to SR-Constituents along with the minutes of PCSC-75 meeting issued vide

SRPC letter dated 17.07.2018), accepted the following reports:

Reports of the Consultant M/s Powertech Labs Inc. on Task IV, V & VI under Package

B.

As decided in the GSC-5 meeting, an action plan for implementation of various

recommendations for all Tasks under Package-A & Package-B is under finalization by CEA

in consultation with CTU & POSOCO. After finalization, the same would be made available

to SR-Constituents for appropriate action, please.



48 OVR Grading of 400 kV and 765 kV Transmission Lines of Southern Region

In the past one year, a number of new 400 kV and 765 kV transmission lines have been added

to SR-Grid in addition to reconfiguration (including LILO) works of the existing 400 kV and

765 kV transmission lines. In this regard, a comprehensive exercise of OVR grading for

400 kV and 765 kV transmission lines of Southern Region (existing as on March, 2018) has

been carried out, and the new OVR Gradings proposed to be adopted for these lines (along

with study results) had been circulated to all Constituents for modifications/ omissions/

comments. After duly incorporating Constituents' comments, the final OVR gradings to be

adopted for 400 kV and 765 kV lines in the Southern Region had been issued vide SRPC letter

dated 01.05.2018 for implementation with immediate effect. The above OVR gradings have

also been kept in SRPC Website for easy reference.

49 COMPLIANCE OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE

TRANSMISSION OF ELECTRICITY), REGULATIONS 2017

49.1 A Special Meeting was held on 08th

May 2018 at SRPC, Bengaluru (Minutes available on

SRPC website) on compliance of CERC (Communication System for inter-State

Transmission of Electricity) Regulations, 2017 which had come into force w.e.f. 01.07.2017.

There were two activities assigned for RPCs - periodic auditing of communication system

and ensuring cyber security third party audits. Audit procedure (Annexure-CI) had been

finalized in that Meeting and the same is put up for kind approval of the TCC/SRPC. All the

entities had agreed for annual periodicity (FY) for Cyber Security Audit.

49.2 A Sub Group Meeting to finalize the guidelines for Cyber Security Audit was conducted on

13th

June 2018. Further on the request of the constituents, a guiding Code for Cyber Security

audit (Annexure-CII) has been prepared in consultation with the stake holders and circulated

to all the constituents.


TCC had recommended the Audit procedure for implementation.

TCC had recommended for annual periodicity (FY) for Cyber Security Audit and noted

Cyber Security guideline.

49.4 SRPC approved the TCC recommendations.

50 SPECIAL MEETING ON THE TRIPPINGS OF POLES - 1 & 2 AT HVDC

GAJUWAKA SS OF POWERGRID (SRTS-I)

A Special Meeting was held on 02nd

April, 2018 at RHQ POWERGRID (SRTS-I), Hyderabad

to deliberate on all outstanding issues involved in the recent HVDC Gajuwaka Pole trippings -

esp. two categories of trippings that occurred in the past one year - viz., Pole-1 trippings on

A.C. auxiliary supply failure and Pole-2 trippings on ferro-resonance detection. The following

issues were discussed in the meeting:


Deliberations on HVDC Pole trippings in the past one year

Resolution of Issues w.r.t. Pole-1 Trippings (ALSTOM make)

Resolution of Issues w.r.t. Pole-2 Trippings (ABB make)

Compliance of Protection Audit Recommendations (PAR) pertaining to Gajuwaka (HVDC

& HVAC) Substation

The issue had also been raised in the Operational Feedback (Jan-Mar 2018) by POSOCO. The

minutes of the meeting were circulated vide SRPC letter dated 11.04.2018.

In this regard, the compliance status furnished by PGCIL (SRTS-I) w.r.t. various measures

suggested [copy enclosed at Annexure – CIII] was reviewed in the PCSC-76 meeting held on

26.07.2018. It was noted that necessary action had been taken by PGCIL (SR-I) in attending to

issues relating to (i) Pole-1 trippings on AC auxiliary supply failure, and (ii) Pole-2 trippings

on Ferro-resonance detection [short-term & medium-term]. Similarly, as agreed in the special

meeting, PGCIL (SR-I) was also requested to kindly initiate necessary action, as a long-term

measure for avoiding pole trippings under ferro-resonance conditions, to undertake necessary

refurbishment works of controller protections at Jeypore end for detecting ferro-resonance

locally at FSC location (Jeypore end) and effect automatic by-passing of FSCs by putting

necessary infrastructure in place at Jeypore end.

51 SPECIAL MEETING ON THE PENDING PROTECTION ISSUES OF

PUDUCHERRY SUBSTATIONS

A Special Meeting was held on 20th

July, 2018 at Puducherry ED HQ to deliberate on all

outstanding protection issues involving Puducherry substations. The following issues were

discussed in the meeting:

Root-cause Analysis of the Villianur GD‟s on 30.05.2018, 05.06.2018 & 15.06.2018

Review of status of implementation of Protection Audit Recommendations of Villianur and

Bahour Substations.

Review of compliance status of the recommendations given in the special meeting held

on 3rd

January, 2017 w.r.t. Neyveli Grid Disturbance on 25.11.2016.

The minutes of the meeting were circulated vide SRPC letter dated 30.07.2018. PED was

requested to kindly take appropriate action w.r.t. measures suggested/ recommended and

ensure that protection systems in place at their substations are maintained in healthy

condition.

52 UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH

TRANSMISSION NETWORK

52.1 In the earlier Meetings 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.


52.2 Transmission scheme for Wind Energy Zones (WEZs) in Southern Region

In the 42nd

SCPSPSR, representative of POWERGRID stated that Govt of India has set an

ambitious target for 175GW renewable capacity by 2022, out of which 60 GW is envisaged

to be set up through wind power projects. In view of the wind capacity expansion plan as

well as connectivity applications received in ISTS for wind capacity & SECI bids, it is

expected that wind capacity may cross the milestone of 60 GW in next 3-4 years. SECI has

already bid 6050 MW ISTS connected wind bids (awarded-4050 MW) and planning to bid

10,000 MW in FY18-19. Therefore, there is a requirement of development of ISTS

infrastructure in wind rich pockets. To identify actual developable wind potential by 2022,

several rounds of discussions were held with MNRE & other stakeholders. Further, wind

energy zones along with projected capacity in each WEZ were identified, which may come

up by 2022 in wind resource rich states were prioritized. Accordingly, five WEZs viz.

Koppal (2,500 MW) in Karnataka, Kurnool (3,000 MW) in Andhra Pradesh, Karur (2,500

MW) in Tamil Nadu, Dwarka (2,000 MW) in Gujarat and Osmanabad (2000 MW) in

Maharashtra were identified for which ISTS substation/infrastructure was decided to be

developed/made available.

After deliberations, it was decided that due to large scale integration of renewable

generation in SR, detailed study considering the proposals of renewable rich states of SR

and CTU need to be carried out. The results of the study would be discussed in joint study

meeting.

Joint System Study Meeting of SR was conducted on 10th

& 11th

May 2018 at SRPC,

Bengaluru (refer Annexure-XL)

Comments furnished by TANTRANSCO are enclosed at Annexure-CIV.


53 PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS

53.1 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.

53.2 Concerned entities need to kindly initiate/continue necessary steps to ensure that Patrolling

and Maintenance is carried out regularly as per the Patrolling Guidelines.

53.3 SRPC noted the above

54 ROSTER FOR HOSTING THE SRPC MEETINGS

As per the roster the SRPC meetings are to be hosted in the following sequence:


(1) UPCL (2) JSWEL (3) NPCIL (4) SGPL

UPCL agreed to host the next SRPC Meeting.

55 CONLCUSION

Chairperson, SRPC thanked all the participants for lively deliberations. On a number of

issues consensus had been arrived while on some other issues, further action like having

special meeting or further deliberations may be required. It shows that SR is a vibrant

region in power sector. Wherever support from MoP, CERC, CEA, Railways and Coal

companies is required the issues are being flagged to them. He opined that Railway Board,

MCL, SCCL and other coal companies need to kindly understand the issues being faced at

the generating end. In addition, the wind and solar power was becoming a reality over a

period of time and thus APSPCL had been requested to be part of the meeting to be

appraised of the grid requirements. IWPAI had also requested to participate in the Meeting

as a special invitee and they are present here. The entire sector from thermal, hydel, RE and

transmission had been discussed and the forum had tried to resolve the issues. He thanked

all for their active participation and support in strengthening the SRPC. He once again

thanked PGCIL for making excellent arrangements.

56 DATE & VENUE OF THE NEXT MEETING OF SRPC

The date and venue would be finalized in consultation with Chairperson, SRPC.

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Documents

Contents 1. INTRODUCTION 3 2. rdCONFIRMATION OF ...Pavagada, a 2,000 MW Solar Power Park is being developed by KSPDCL and SR-II is responsible for evacuation of this power. As a Green