contents 1. introduction 3 - southern regional power …

Agenda for the 33rd TCC & 34th SRPC Meetings to be held on 10 &11.08.2018

CONTENTS

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

2. CONFIRMATION OF THE MINUTES OF THE 32nd TCC & 33rd SRPC MEETINGS .............................................. 3

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

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

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

6. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION ................................................................................ 5

7. MONITORING OF SCHEMES FUNDED FROM PSDF ......................................................................................... 5

8. TRANSMISSION CHARGES / SHARING RELATED ISSUES ................................................................................. 6

9. OPTIMUM HARNESSING OF RE IN SOUTHERN REGION ............................................................................... 10

10. ISSUES WITH OA CONSUMERS ..................................................................................................................... 12

11. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER ENVIRONMENT

(PROTECTION) AMENDMENT RULES, 2015 .................................................................................................. 12

12. COAL ISSUES.................................................................................................................................................. 14

13. STATUS OF DC/GENERATION IN ISGS ........................................................................................................... 15

14. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY ..................................................................... 16

15. TTC/ATC ........................................................................................................................................................ 18

16. ISSUE OF PREVAILING OVER VOLTAGES IN SR GRID ..................................................................................... 19

17. ISSUES IN RESPECT OF NPCIL ........................................................................................................................ 20

18. UPCOMING TRANSMISSION SYSTEM ........................................................................................................... 23

19. SCHEDULING OF MACHKUND AND TB DAM ................................................................................................ 31

20. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ................................................................ 31

21. NEW PROJECTS OF STATE SECTOR & IPP ...................................................................................................... 33

22. REVIEW OF ULDC / SCADA/COMMUNICATION ............................................................................................ 34

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

24. EMERGENCY RESTORATION SYSTEM (ERS) .................................................................................................. 36

25. ADOPTION OF UNIFORM PROCEDURE TO PREPARE MERIT ORDER DESPATCH LIST ................................... 37

26. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR .............................................................. 37

27. NON-AVAILING OF OCC APPROVED SHUTDOWN ......................................................................................... 42

28. STATUS OF PHASE-I AND PHASE-II OF PROTECTION AUDIT RECOMMENDATIONS ..................................... 44

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

SOUTHERN REGION ...................................................................................................................................... 46

30. COMPLIANCE STATUS OF NEW PROTECTION AUDIT RECOMMENDATIONS ................................................ 46

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

SOUTHERN REGION ...................................................................................................................................... 47

32. REVIEW MEETING ON COMPLIANCE OF PCSC RECOMMENDATIONS .......................................................... 48

33. COMMERCIAL COMMITTEE ISSUES .............................................................................................................. 48

34. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION .............................................................................. 51

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 ...................................................................... 61

36. GRID OPERATION .......................................................................................................................................... 62

37. REIMBURSEMENT OF SRPC EXPENDITURE ................................................................................................... 67

38. OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE .................................................................... 67

39. RSD & TECHNICAL MINIMUM ....................................................................................................................... 67

40. FREQUENT REVISION OF OUAGE PLAN BY ISG STATIONS ............................................................................ 68


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

SOURCES ....................................................................................................................................................... 68

42. SCHEDULING OF ANANTHAPURAMU ULTRA MEGA SOLAR PARK & RAMAGUNDAM SOLAR

PROJECT ........................................................................................................................................................ 69

43. GRID STUDY COMMITTEE (GSC) MEETINGS ON PACKAGE-A & PACKAGE-B ....................................... 70

44. OVR GRADING OF 400 KV AND 765 KV TRANSMISSION LINES OF SOUTHERN REGION ............................... 71

45. COMPLIANCE OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE TRANSMISSION OF

ELECTRICITY), REGULATIONS 2017 ............................................................................................................... 71

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

(SRTS-I) – REG ............................................................................................................................................... 71

47. SPECIAL MEETING ON THE PENDING PROTECTION ISSUES OF PUDUCHERRY SUBSTATIONS...................... 72

48. UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH TRANSMISSION NETWORK ............. 72

49. PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS ....................................................... 73

50. ROSTER FOR HOSTING THE SRPC MEETINGS ................................................................................................ 73

51. DATE & VENUE OF THE NEXT MEETING OF SRPC ......................................................................................... 73


SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

AGENDA FOR THE 33rd

TCC & 34th

SRPC MEETINGS TO BE HELD ON 10

th &

11th

AUGUST 2018 AT COIMBATORE

1. INTRODUCTION

The 33rd

Meeting of the Technical Coordination Committee of SRPC & 34th

Meeting of

the Southern Regional Power Committee (SRPC) would be held on 10th

& 11th

August

2018 respectively at Coimbatore.

These Meetings would be kindly hosted by SRTS-II, PGCIL.

2. CONFIRMATION OF THE MINUTES OF THE 32nd

TCC & 33rd

SRPC

MEETINGS

2.1 Minutes of the 33rd

Meeting of SRPC held on 17th

February 2018 at Puducherry had

been circulated vide letter dated 13th

April 2018.

2.2 Minutes of the 32nd

Meeting of TCC held on 16th

February 2018 at Puducherry had been

circulated vide letter dated 27th

March 2018.

2.3 Minutes of the Meetings may kindly be 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 is not getting fully utilized on account of PPA provisions / 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 states and the

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

Subsequently, the following was noted:

In the Meeting held at Chennai 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-I) had circulated a Note regarding

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

incentives /penal rates 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 essential from grid operation / reliability

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

/ DISCOMs / Commercial sections and then the matter could be taken up with RE

generators.

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

arriving at a consensus on this subject in Southern Region and to take the matter

further.

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

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


In the Special Meeting conducted 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 to review these aspects.

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

support by the generating stations including RE with Hon’ble CERC. It was brought to

kind attention that reactive accounting for generators needs to be carried out so as to instill

desired grid discipline.

3.3 In day to day operations it was seen for instance 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 are 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 was also discussed in the

75th

Meeting of Protection Sub Committee held on 28th

June 2018. It was proposed to

constitute a Group of Officers from SRLDC, SRPC and States who would visit major RE

nodes facing high voltage scenario and suggest any improvement in the Operating

Procedure

4. RAMP RATES

4.1 As can be kindly appreciated, 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-III.

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 of machines; even same capacity units may be having different

parameters. Further, even for the same make of machines, the year of manufacturing also

mattered. It was noted that Kudgi, NTPL and NTECL generating units had had come after

2010. In case any issue is being faced by generators in adhering to the Regulations, they

may need to kindly approach CEA/Regulators. NTPC, NLC, NTPL and NTECL had

agreed to discuss this matter with their engineering division so as to 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-IV) had taken up the issue of

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


4.4 SLDCs may also need to kindly ensure enhanced ramp rates from state generators. All

generating units irrespective of control area jurisdiction/ownership need to contribute with

higher ramp rates.

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-V) SRPC vide

letter dated 04.06.2018 had informed TANGEDCO that this 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.

Preliminary discussions have taken place with IIT Mumbai in this regard. It is learnt that

the cost for 10 licenses would be around Rs 35 lakhs per year. The way forward in this

regard may kindly be deliberated.

6. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION

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 be 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 was refined and the 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 have informed that they had commenced the

procurement process. As they have to go for competitive tendering, it could take about 3

months before they can sign the 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 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 30th

June 2018 is given below, please:

Sl.

No.

State/Entity Receive

d

Sanction

ed

Under

approval

Input

sought

Not

eligible

Grant

sanctioned

Disbursed

1 AP 8 3 4 0 1 295.2 29.55

2 Karnataka 7 3 2 2 0 205.06 26.85

3 Kerala 7 6 0 0 1 581.8 164.28

4 TN 15 4 2 9 0 459.39 41.03

5 Telangana 12 5 2 4 1 247.72 49.93

6 Puducherry 2 2 0 0 0 13.19 0.95

7 PGCIL, SR 1 1 0 0 0 378.04 37.80

8 SRPC 2 2 0 0 0 30.59 19.01

8. TRANSMISSION CHARGES / SHARING RELATED ISSUES

8.1 The issue of Transmission charges / sharing was discussed in the 38th

Meeting of

Commercial Sub Committee held on 29th

June 2018. Based on the deliberations in the

CCM, Chairperson, SRPC vide letter dated 03.07.2018 (Annexure-VI) had taken up the

following issues with Chairperson, CERC:

a) Determination of Relinquishment Charges

Early resolution of Stranded Capacity and relinquishment charges which are already

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

help relieve financial stress on DICs

b) Transmission charges related with RE projects

Issues involved in implementation of policy regarding waiver of transmission

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

letter dated 23.08.2017. This 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 some time gap between issuance of provisional Tariff

Order and Final Tariff Order. During this interim period, charges are being

recovered through POC mechanism from existing DICs, thus causing upfront

financial burden.

8.2 TANGEDCO vide letter dated 02.07.2018 (Annexure-VII) 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

transmission charges as per provisions of Sharing Regulation. 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, 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 orders related to the above IPPs?

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

difficulties in implementing the orders.

iv. Details of assets / LTA quantum to be considered for bilateral billing

furnished to SRPC.

Implementing Agency (NLDC) / CTU are 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 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 earlier Order dated 30th

September, 2016 and Order

dated 14th

June, 2017, it is 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 are kindly requested to elucidate on how the same 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 direction of Hon’ble Commission in Order dated

30.06.2016 in respect of Petition No.26/TT/2016 should have been compiled by CTU

and the IA. 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 Anantapur 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 These issues were discussed in the 38th

CC Meeting held on 29.06.2018, wherein PGCIL

had explained that the relinquishment was being allowed as per the prevailing CERC

Regulations. Further the relinquishment charges were to be determined as per the final

order of CERC in Petition No 92/MP/2014. The same would be passed on to the existing

DICs as and when the charges are determined and received. CTU is diligently following

the regulations/CERC Orders from time to time.

8.4 SRPC vide letter dated 04.07.2018 (Annexure-VIII) had taken up the issue with CTU. It

was pointed out transmission charges for delay in commissioning of solar power

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

liability for payment by thermal and hydro generating stations. Implementing Agency

(NLDC) / CTU are kindly requested to furnish their views on the matter.

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 this

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-IX) 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 GM Division,

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-X) to Chairman, TNEB had

requested to kindly consider signing the Overarching Agreement so as to avail

opportunities in real time operation

9.1.5 The following had been noted in the earlier Meetings with regard to implementation of

SAMAST:

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

Hon’ble CERC and to NLDC for funding.

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

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

project was likely to be completed by 25.05.2018.

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

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

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 were 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 please:

State PSP Scheme Status

Andhra Pradesh Upper Sileru (1000 MW) DPR being prepared

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

SCPSPSR : 2020-21

Sillahalla-I (4x250 = 1000

MW)

42nd

SCPSPSR : 2023

onwards

Sillahalla-II (4x250 = 1000

MW)

4 projects on existing sites

Karnataka Sharavathy (2000 MW) PFR submitted to MoEF

Varahi


Kerala Sholayar-I (810 MW) Survey and investigation

(S&I)/implementation could

not be taken up for want of

forest clearance

Sholayar-II (390 MW)

Poringalkuthu(80 MW)

10. ISSUES WITH OA CONSUMERS

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

Power Exchange for short duration of time when PX rates are less while during other times

they were availing power from DISCOMs.

10.2 During last year KSEBL had suspended NOC of such consumers but these 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 forum had noted that the following modalities / procedure for granting OA to

consumers in states like Gujarat, Rajasthan and Himachal Pradesh are in vogue:

OA is granted on RTC basis and not for just a 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 has to be filed by

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

consumers have to file the O.A. application by 15th of the previous month.

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

efficient manner.

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

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

approval of the SERCs.

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, 1

st Jan 2004 to 31

st December 2016 and beyond 1

st January

2017. Existing as well as new plants were required to meet standards by the stipulated time

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

discussed in SRPC as well as Subcommittee Meetings


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 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-XI) had requested 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 thermal stations for early

installation of Pollution Control Equipment.

11.5 MoP vide letter dated 30.05.2018 (Annexure-XII) 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-XIII) had forwarded CEA

letter seeking updated information in respect of status of implementation of 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). It was mentioned in the CEA letter that the report will be submitted to

Hon’ble Supreme Court every quarter.

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 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.

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 is 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 located in Southern Region. Also BOB rakes need to be

allowed over long distance for power plants such as Simhadri and other plants with

BOB rakes unloading facilities. 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 also 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-XIV) had taken up the concerns of SR Thermal generators with Chairman,

Railway Board.

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

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

Railways. Daily requirement had been specified as 2 rakes/day from BBMT siding & 3.2

rakes/day for Dr NTTPS, 1.33 rakes/day for RTPP and 2 rakes/day for RTPP stage-4.

12.4 NTPL vide letter dated 31.05.2018 (Annexure-XVI) 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-XVII) on account of fuel shortage.

12.6 SRLDC had prepared a link wherein details of coal need to be uploaded

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

every day (critical since information is shared with MoP).

12.7 APGENCO vide letter dated 5th

July 2018 ( Annexure-XVIII) have 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 thermal stations. This is despite constant

pursuance with SCCL and CIMFR.

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 please:

Station Feb-18 Mar-18 Apr-18 May-18 June-18

NTECL,

Vallur

DC % 67.19 72.63 98.18 80.23 64.43

PLF (on Actual)

%

56.43 62.88 85.91 97.57 48.87

NLC TS

II Exp

DC % 44.14 31.52 25.78 30.62 16.72

PLF (on Actual) 29.51 32.43 26.34 30.97 17.26

MAPS PLF (on Actual) 51.24 51.04 50.20 49.03 50.51

https://goo.gl/y3LL4n



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 the

beneficiary, DC being the 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 also requested for maximization of consent for trading.

It had been noted that Unit-III of NTECL which was out since 06.06.2017 had come back

on bars on 27th

February 2018.

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.

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

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

of India’s large inter-connected grid.

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

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

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

st

March, 2017.

……………

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

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

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

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

due consideration to the experience gained in the implementation of Spinning

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

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 related issues was conducted at SRPC on 28th

March 2018 (MOM

available on SRPC website). The following highlights may kindly be 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, 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.

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.

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 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 opined that this

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 to

take proactive and appropriate steps to ensure consistency in data. The issue needed

due attention it deserves being critical in grid operation. Entities need to have

dedicated team with 24x7 support specifically at SLDC/RLDC/NLDC/CTU/STU.

It was noted that 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 needs to be implemented pan India for all generators- ISGS,

State generators, IPPs, MPPs etc.

Forum strongly advocated for AGC for RE generators also. 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 AGC implementation by USAID / PRDC for which KPCL had

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 had 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.

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 Meeting of

SRPC.

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

of Nodal Officer would be furnished within a week.

The following is the status in this regard please:

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 Meetings of OCC:

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.

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

purpose of operationalization and grant of MTOA.


SRPC 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 05th

March 2018 (Annexure-XIX).

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

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 13th

March 2018 (Annexure-XX) had again taken up the issue

with CTU and requested that required details of terminal equipment may please 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 line, use of

HTLS etc.

CTU is kindly requested to furnish 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.

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 on substation equipment including ICTs,

Reactors, CVTs, CTs etc. Life span of equipment is also affected adversely leading to

early failures.

16.2 In the Operational Feedback for the quarter (January-March 2018), POSOCO 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 the period

February 2018 to June 2018 are given below please:

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 prevailing high voltage at 400 kV Urvakonda and 400 kV Jammalmadugu

sub-stations was taken up with APSLDC vide SRPC letter dated 03.07.2018

(Annexure-XXI). As mentioned earlier, 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.

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 of Southern Region beneficiaries to NPCIL had been

discussed in the 33rd

Meeting of SRPC. All beneficiary states had assured of early

settlement of the dues. The issue was regularly followed up by NPCIL stations and

MS, SRPC and the same was further discussed in the 38th

Meeting of CC. Director (F),

NPCIL vide letter dated 31.05.2018 (Annexure-XXII) had expressed concern on

significant dues. Outstanding dues to NPCIL as discussed in 38th

CCM (29.06.2018)

are as follows:

Sl.

No.

Entity MAPS

as on

30.05.2

018

KGS

(as on 26.6.18-

excluding May

2018 energy bill)

KKNPP as on 27.06.2018

Bill

Amount

Delayed

payment

charges

1 TNEB 188 184.89+119.28 989.19 138.446

2 HESCOM

(Karnataka) 4 191.02+71.59 167.672 25.221

3 Telangana 9 150.31+5.49 23 6

4 GESCOM

(Karnataka) 2 56.18+4.76 65.1925 4.484

5 CESCORP

(Karnataka) 2 33.21+3.65 37.355 3.286

6 APTRANSCO 7 56.17+10.9 1.198 0.642

7 PED

(Puducherry) 3 13 20.71 1.886

17.2 Part load operation/Reserve shutdown/frequent changes in revival of KKNPP units

In the 32nd

Meeting of TCC, 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 also pointed out that during peak demand months (Feb to Apr)

both the units at KKNPP need to be in service. The 1,000 MW size of KKNPP units

has significant impact on the LGB and even affects the power market price also.

Frequent change in revival was completely distorting purchase planning and LGB of

the control area. TN being 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 needs to be

contemplated by NPCIL.

Chairperson, SRPC vide letter dated 11.04.2018 (Annexure-XXIII) had taken up the

pertinent issues with CMD, NPCIL.

TANTRANSCO vide letter dated 11.06.2018 (Annexure-XXIV) had suggested that

either one of the units be in service till September 2018 end, while both units would

need to be available from October 2018.

Director (F), NPCIL vide letter dated 31.05.2018 (refer Annexure-XXII) had requested

that 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, the entitlement of these beneficiaries

from Kudankulam power of NPCIL could be reduced to the extent of surplus power

available even if it is more than 15% enabling NPCIL to sell it to others for cash and

serve purpose of both energy consumers and producers.

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 in future not schedule BSD for any of its units during

Jan to April.

All units would be planned for BSD only during the period June to December 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 Unit-I, on similar lines to KKNPP.

MAPS Black Start Mock Drill 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 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 MVAR as per Capability Curve above 225

kV while there would be no MVAR 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 tendering activities of second

125 MVAR reactor. The same needs to be confirmed along with detailed

commissioning plan in the 34th

Meeting of SRPC scheduled in August 2018.

During testing activities of generator 3 & 4 with respect to MVAR absorption, Kaiga

GS would also involve SRPC & SRLDC.

Kaiga GS would endeavor to support the grid within mandated provisions of

IEGC/CEA & CERC Regulations.

17.7 2x125 MVAR Reactor commissioning at Kaiga GS (meeting held on 22.06.2018)

Kaiga GS/NPCIL had informed that technical bids had been opened for the first 125

MVAR reactor on 20th

June 2018. The reactor was planned to be commissioned by

December 2019.

Kaiga GS/NPCIL had assured that bidding activities for second 125 MVAR reactor

would also be initiated.

As also discussed in the Special Meeting held 22.06.2018 held at Kaiga GS,

Chairperson, SRPC vide letter dated 26th

June 2018 (Annexure-XXV) had taken up

this issue with CMD, NPCIL

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 through

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 had been reviewed and it has been decided to keep settings as 200 msec for

all. Approval letter from HQ had been received and the same 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 operation 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 works in Kaiga complex.

The works would be completed within 3-4 months since 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. It was agreed that Kaiga GS would formally take

up RTU related issues with SR-II, PGCIL with a copy to SRLDC & SRPC. SRLDC

would endeavor to facilitate these works through SR-II; however onus of ensuring

SCADA compliance rested with Kaiga GS.

Kaiga GS agreed to extend the digital status under URTDSM within a month.

KKNPP had informed that rectification of the other reactor would be taken up in

April/May 2018 and was 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 was released for procurement of the CVTs. A/R for

the lines would be implemented after receiving the CVTs.

18. UPCOMING TRANSMISSION SYSTEM

18.1 42nd

Standing Committee on PSPSR

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).

18.2 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-XXVI) 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.’

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.

b) 765 kV Angul - Srikakulam PS D/C

Corridor

Main corridor commissioned.

Other associated elements by July

2018.

32nd

TCC: PGCIL informed that Garividi- Srikakulam PS was expected by

May/ June 2018. AP informed that downstream system is ready.

OCC update: To be charged in July 2018.

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 January to March

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 – Cudappah D/C

c) 400 kV Chilkaluripeta – Narasaropeta D/C

d) 400 kV Cudappah – Hindupur D/C

e) 400 kV Cudappah – Madhugiri

18.3.2 Updated detailed status of upcoming inter regional schemes is furnished at Annexure-

XXVII.

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

Raichur- Sholapur line (Out of planned 18 elements)

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

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

Sl.

No

Name of Transmission Element

1 400 kV Tumkur-Yelahanka D/C line ; PGCIL (132 Ckm)

32nd

TCC: Sep 2018; CEA (May 2018): Dec 2018; Severe ROW in Karnataka.

Balance work re-awarded in Dec'17. Work under progress.

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

32nd

TCC: March 2018

Special Meeting (09.07.2018) : KIADB has to procure and hand over the land.

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

32nd

TCC: March 2018

Special Meeting (09.07.2018): KADB has to procure and hand over the land.

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.


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

32nd

TCC: March 2018

CEA (May 2018): Sep 2018, Severe ROW in Karnataka. Obstruction is being

removed progressively with the help of Police protection.

Covered under PRAGATI.

2 Salem New – Madhugiri 765 kV S/C line; 219 ckm ; (PNMTCL) (A subsidiary of

PGCIL)

32nd

TCC: June 2018

CEA (May 2018): Sep 2018; Severe RoW issues being faced in Karnataka, issue

highlighted to PMO level.

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: June 2018, 220 kV D/C line to Basavana

Bagewadi, 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

31st TCC: Nov 17

TSTRANSCO : Jagityal – Nirmal; 148 ckm

31st TCC : Line ready; Nirmal SS by Nov 2017

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

7 Bhadradri TPP (Manuguru) (4x270 MW), TSGENCO

TSTRANSCO: 400 kV Julurupadu SS - Manuguru TPP D/C : 2018-19, 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

8 Kothagudem TPS St-VII (1x800), TSGENCO

TSTRANSCO : 400 kV D/C Julurupadu - KTPS (Stage-VII): -, 400 kV Julurupadu –

Jangaon D/C : - Jangaon SS: -

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

Gulbarga 400/220 kV substation- 2 x 500 MVA, Yermarus TPS - Gulbarga 400 kV

D/C line (QM),

400 kV SS at Chikkanayakanahalli – 2 x 500 MVA (39th

SC) Alternate site at


Bindikere is under consideration. Land acquisition is under progress.- CEA (May

2018): Sep 2018

LILO of Nelamangala – Talaguppa 400 kV D/C at CN Halli, 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

De-link 400 kV S/C RTPS-BTPS-JSW-Guttur with JSW Bus

Additional JSW TPS – BPS 400 kV D/C (QM)

400 kV BTPS-Guttur D/C (QM)

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

32nd

TCC: June 2018

CEA (May 2018): Sep 2018 - Severe ROW problem faced in Karnataka. With the

support of state Govt. ROW issues are being resolved.

12 400 kV Mangalore (UPCL ) -Kasargode-Kozhikode; TBCB

13 400 kV Edamon-Kochi; 286 ckm; PGCIL

Being monitored under PRAGATI.

32nd

TCC: May 2018

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.

14 LILO of 230 kV Neyveli- - Bahour at Karaikal

32nd

TCC: April 2018

CEA (May 2018) : NLY- Karaikal – Aug 2018

15 400 kV Pavagada – Hiriyur D/C line; PGCIL

32nd

TCC: March 2018

CEA (May 2018): Dec 2018- Slow progress due to ROW problem.

16 400 kV Hiriyur – Mysore line; PGCIL

32nd

TCC: June 2018

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.

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

18 FSC at Pavagada; PGCIL

32nd

TCC: July 2019

18.6 Associated Transmission Evacuation Schemes in Tamil Nadu

Updated status of the following stations, evacuation schemes finalized in the 37th

SCPSPSR, which were modified in the following Standing Committee Meetings, is given

below please:


Generating Station Likely COD Evacuation Status

Ennore TPS Expansion – 1 x

660 MW

2019-20

Ennore SEZ (NCTPS Stage-

IV) – 2 x 660 MW

2018-19

NCTPS Stage III – 1 x 800

MW

2019-20 41st SCPSPSR: 2019

Ennore TPS Replacement – 1

x 660 MW

2019-20 41st SCPSPSR: 2020

SEPC (1x525) October 2018 41st SCPSPSR: Require

start up power for its

Auxiliaries by April 2018.

SEPC-Thennampatty

400/230/110 kV 41

st SCPSPSR : April

2018

SEPC- Ottapidaram 400kV

(Regular evacuation)

765/400 kV, 2 x 1500 MVA

Ariyalur SS

31.3.2019 Work awarded to M/s BHEL

on 31.03.2017.

765/400 kV, 3 x 1500 MVA

North Chennai PS (GIS) 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

process. Approval of

BLTC to recommend to

place before board.

400 kV Ennore SEZ- Ennore

to ETPS Expn CEA (May 2018): April

2019

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 substations of POWERGRID

Sl.

No

Name of

Substation

MVA

Capacity

220kV

Bays

Expected

Schedule of

Substation

Remarks

1 Tumkur

(Vasantnarsa

pur)

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


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 kVdownstream 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 220kV downstream Link

Bidadi-Kumbalgodu expected by Mar’20.

4 Hiriyur 2 x 315 6 Commissioned Construction of downstream




SCPSPSR: 2 Nos 220kV downstream links i.e. Hiriyur-

Hiriyur (KPTCL) 220 kV S/C line & for 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




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 220kV 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

220kV 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.

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 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 is necessary to carry out necessary system improvements aimed at damping the

resonant condition.

HVDC links are critical to integrated power system operation, since 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 surprises in real-time operation.

Vide letter dated 09th

March 2018, NLDC with regard to frequent occurrence of

ferroresonant phenomenon involving Gazuwaka HVDC had communicated its concerns

to PGCIL.

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 HVDC link. There had been multiple pollution related trippings,

which warrant 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 with regard to frequent trippings on

HVDC Talcher – Kolar bipole had been communicated to PGCIL.


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 on 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 400 kV KKNPP- Tuticorin PS sections.

Additionally commissioning of the new 400 kV lines connecting Tirunelveli wind station

to Tuticorin PS will further aggravate the situation. POSOCO had stated that there is a

need to review the evacuation transmission system from KKNPP.

After deliberations, this issue was 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.

d) Transmission Line constraints:

400 kV Nellore Pooling Station -Nellore D/C line

400 kV Gooty-Nelamangala line & 400 kV Gooty- Somanahalli line.

400 kV Udumalpet- Palakkad D/C line

31st TCC: KSEBL had stated that there was no constraint on this line. SRLDC

stated that they would examine the matter.

400 kV Hiriyur-Nelamangala D/C line

220 kV Bangalore Metro Network

Overloading of 230 kV Shoolagiri-Hosur (TN)-Yerrandahalli-Somanahalli S/C line

Constraints in Nagjheri PH evacuation

Constraints in Chennai 230 kV System

Overloaded 230 kV Lines in Tamil Nadu

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 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 has to look into the issue and may plan

additional ICTs/ replacement of ICT by higher capacity.

400/220 kV 3 x 500 MVA ICTs at Nelamangala

400/220 kV 3 x 500 MVA ICTs at Somanahalli

400/220 kV 3 x 500 MVA ICTs at Hoody (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 SS, the loading was likely to

come down)

400/220 kV 2 x 315 MVA ICTs at Guttur

400/220 kV 2 x 315 MVA ICTs at Hiriyur

400/220 kV 1 x 500 MVA + 1x315 MVA ICTs at Narendra

400/220 kV 2 x 315MVA ICTs at UPCL

400/220 kV 3 x 315MVA ICTs at Shankarapally

41st SCPSPSR: 1x 500MVA 400/220kV transformer (4th 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. Hence

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 400kV 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.

19. SCHEDULING OF MACHKUND AND TB DAM

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-XXVIII) by SRPC. In this regard, the letter dated 02.07.2018 received from

TSTRANSCO on the subject was also enclosed.

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 please:

Station Unit

Installed

Capacity

MW

Scheduled date of

synchronizing /

commissioning Remarks

NTPC

Kudgi TPS

Stage-I

III 800 August 2018 Unit-III: Trial operation

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 32nd

TCC:

U-I CoD May 2020

(Synchronization by

Mar 2020)

U-2 CoD Dec 2020

(Synchronization by

Sep 2020)


Pudimadaka AP 4 x 1000 52 Months from Zero

Date

85 % share to AP.

Zero date yet to be finalized.

AP had requested NTPC to

firm up the zero date at the

earliest.

31st TCC:

NTPC had informed that the domestic coal was yet to be tied up. Within

two months, the status would be communicated.

CTU informed that there was no connectivity / LTA application pending

with them.

NLC

New Thermal

Power Project

I 500 October 2018

II 500 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-XXIX) 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.

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 informed that they had

not received any LTA

application from NPCIL for

Kudankulam - 3 & 4 units.

Any system strengthening

would be planned on receipt

of the LTA application based

on proper studies.

BHAVINI

Kalpakkam

(PFBR)

I 500 Synchronization by

2018-19

COD by 2018-19

32nd

TCC:

Kanchipuram SS – TANTRANSCO informed that the S/S would

come up by March 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

21. NEW PROJECTS OF STATE SECTOR & IPP

21.1 Updated status of new projects of State sector is furnished below please:

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 2019-20

41st SCPSPSR: 2019

7 North Chennai Stage IV TN 2 x 800 Beyond 2019-20

8 Ennore TPS Exp TN 1 x 660 2018

9 Ennore replacement TN 1 x 660 41st SCPSPSR: 2020

10 Udangudi Stage I TN 2 x 660 2020-21

11 Uppur TPP (TBCB) TN 2 x 800 2019-20

12 Manuguru PPP Telangana 4 x 270 U1: March18

U2: June18

U3: Sep 18

U4: Dec 18

13 Kakatiya TPP Stage III Telangana 1 x 800 Not decided

14 Kothagudem TPS Phase

VII

Telangana 1 x 800 2018-19 (June-18)

15 Damaracherla (Yadadri) Telangana 5x800 U1 & 2 Nov 2020

U3 – 5 2021

21.2 Updated status of new projects of IPPs is furnished below please:

Sl

No.

Name of project Located

in

Capacity

in MW

Commissioning Schedule

/Remarks

1 Meenakshi PH-II AP 2 x 350 2018-19

Untied: 640 MW


2 East Coast Energy

Thermal

AP 2 x 660

2018-19

AP : 300 MW

3 Thermal Powertech

(TPCIL) Unit-III

AP 1 x 660

2017-18

5 Godhna TPP, Janjir –

Champa Dist,

Chhattisgarh

For

KAR

2 x 800 2017-18

22. REVIEW OF ULDC / SCADA/COMMUNICATION

22.1 Status of pending items is as follows:

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 03and 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.

PGCIL would be floating new combined Open Tender for

Backup SLDCs for AP (Tirupati), TS (Warangal) along-

with few other states.

Periodical testing was being

carried out by SRLDC and

KSEBL.


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.

VC issues

TSTRANSCO Video Conference issue at TSSLDC. There

was disturbance in Video Conference at TS end when

connected to SRLDC.

TSSLDC and SRLDC were

requested to coordinate and

sort out the issue.

Puducherry would take up VC requirement in the financial

year 2017-18.

22.2 ICCP links had failed on 07.02.2018, 08.02.2018 and 23.02.2018. To address these

issues, an urgent Meeting was called on 13.03.2018 (MOM available at SRPC website).

Actionable points need to be complied by all the concerned entities. Further, a Special

Meeting with participation from M/s GE was also conducted on 23rd

May 2018 (MOM

available at SRPC website). The following was agreed in that Meeting:

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 a 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 would

ensure consistent verification of the ISTS drawal and will be helpful during

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.


M/s GE had offered to conduct quarterly Meetings on AMC and other SCADA

related issues which could be conducted through VC or at a common site.

22.3 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-XXX) had communicated its concerns to ED (LD &

C), PGCIL and requested that a review exercise on this matter may kindly be taken

up for Southern Region also.

SR-I & SR-II had clarified that CPU card was to be replaced to handle the present

communication requirements for various applications. Requirement of replacing

the CPU card for ISG stations could be covered in the scope of PGCIL works on

payment basis. ISG stations were requested to revert back on the issue.

Letter dated 15.06.2018 from PGCIL (LD&C) in this regard is given at Annexure-

XXXI, SR-II vide letter dated 27.06.2018 (Annexure-XXXII) had informed that it

was proposed to replace CPU card in all RTUs of POWERGRID stations (SR-II-13

no, SR-I-09 no) .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 can be arrived only after due negotiations with M/s GE as per

standard procurement policy of POWERGRID.

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 furnished at Annexure-XXXIII.

23.2 Feedback on currently installed analytical applications (LSE, VADR, Supervised Zone-3

Distance protection) had been requested from the control centres. PGCIL had agreed to

form a web group of control centres, LD & C, IIT Mumbai etc to exchange information

and for better rectification.

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

TSTRANSCO 1 Tender floated; would be

taken up for PSDF funding.

KPTCL 2 2

KSEBL 1 Tenders to be floated. Would


be taken up for PSDF

funding.

TANTRANSCO 2 As per Minutes of BLTC

held on 03.01.2017,

procurement is put on hold.

Would require PSDF

funding.

PED Nil Nil

PGCIL 4 (2 Nos.

Additional)

4 (SR I &

SR II is

having 2

no. Each)

765 kV ERS (one each for

SR-I and SR-II) Order

placed. Expected by January,

2019.

25. 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 was discussed in 38th

Meeting of Commercial Sub Committee, wherein certain

issues such as 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 were discussed. It was agreed to discuss the nitty gritty of

the issue by a Sub Group. Subsequently, the matter could be taken up with CEA/NLDC,

being a policy issue involving all generators in the country.

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 40

th 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 42

nd SCPSPSR

Raichur 765

kV 2 x 240 42

nd 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 42

nd SC Bus

APTRANSCO

Vemagiri 125

36th

SC

Bus December 2017 – LOA

issued on 18.06.2017

Kurnool 125 Bus December 2017 – LOA

issued on 18.06.2017

Kalpaka 125 Bus March 2018

Chittoor 125 39th

SC APERC approval awaited

Vijayawada 125 39th

SC

It was noted that a

separate reactor at

Vijayawada in scope of

AP had been identified.

The exact location could

be firmed up by

APTRANSCO.

Uravakonda 125 42nd

SC Bus

Uravakonda 80 42nd

SCPSPSR

Jammalmadu

gu 80 42

nd SCPSPSR

Sattenapalli 125 42nd

SCPSPSR

Rachagunneri 125 42nd

SC Bus

Hindupur 80 to 125 42nd

SC Bus

APGENCO

VTPS Stage

IV 125 39

th SC

APGENCO informed that

reactor enquiry was being

taken up.

It was noted that this

reactor was different from

the APTRANSCO reactor.

Polavram

HEP 2 x 125 42

nd SC Bus

KPTCL

Davanagere 125 39th

SC 41st SCPSPSR:

Requirement reaffirmed.

Special meeting

09.07.2018: Approved in

TCCM, estimate under

preparation.

Talaguppa 125 39th

SC


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.

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

TANTRANSC

O

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

TANTRANSC

O/

TANGEDCO

Mettur 125 39th

SC

To be diverted from

Palavadi and works to be

taken up.

TSTRANSCO

Mamidipally 125 36

th SC

Bus

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

Maheshwara

m 125 42

nd 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

TSTRANSCO/

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.

For 2nd

reactor, NPCIL

will get in touch with

PGCIL.

UPCL

Udupi 2 x 125

39th

SC

41st SCPSPSR: It was

informed that the

requirement was assessed

based on system studies,

therefore, it was decided

that the decision taken in

39th

SC Meeting may be

implemented.

SRPC vide letter dated 09.07.2018 (Annexure-XXXIV) 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.

NLC NLC TPS-II

2nd

Expansion 125

42nd

SC Bus

All entities are requested to kindly expedite reactor commissioning, especially since high

voltages are being observed on a 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 32nd

TCC:

March

2019

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 please:

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.


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 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 states that the CPRI Report has been

submitted to NLDC and requested them for further necessary action at their end.

26.4.3 Convener, TESG & Consultant, NLDC vide letter dated 21.05.2018 (Annexure-

XXXV) 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-XXXVI) had submitted its reply in this

regard to Member Secretary, Appraisal Committee.

26.5 Low voltages observed in Bengaluru Area and Central/ North Kerala with

Udumalpet and Arasur areas

A study was undertaken and the following are the recommendations in this regard:

Low Voltage in Bangalore Area was 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.

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:

27.2 It was noted that certain 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 had been 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

would be uploaded on SRPC website.

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. Approval of the Senior Management of Karnataka had not been taken for availing

this 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 only 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 Neyveli-Puducherry line was also extended beyond the approved

dates (12.04.2018-22.04.2018) by PGCIL (revived on 29.04.2018). During such time,

Entity

Feb-18 Mar-18 Apr-18 May-18

Availed % with respect to the OCC

approved outages

AP TRANSCO 35 40 72 75

KPTCL 83 75 57 60

KPCL 100 - - -

KSEBL 100 100 100 100

TANTRANSCO 49 - 35 40

TSTRANSCO 56 100 64 70

PGCIL, SR1 96 100 64 68

PGCIL, SR2 45 75 33 80

NTPC 100 100 100 100

NLC 100 100 100 50

NTPL - - - -

NPCIL 33 0 - 100

PNMTL 0 - - -

CEPL 100 - - -

MTL 0 - - -

RSTCL 0 - - -

UPCL 0 - - -

MEPL - 0 - -

Total 53 66 54 64


Puducherry region as well as Cuddalore area in Tamil Nadu were 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 concerned entities.

A Meeting in this regard was also conducted 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-XXXVII).

As noted in the earlier SRPC Meeting, PGCIL / Transmission licensee would endeavour to

deploy ERS for critical outages. Further, PGCIL was to furnish revival status 2-3 hours

prior to the scheduled time of revival.

28. STATUS OF PHASE-I AND PHASE-II OF PROTECTION AUDIT

RECOMMENDATIONS

28.1 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), final Order of Hon’ble CERC disposing of the Petitions was issued

on 15.12.2016. In this Order, Hon’ble Commission, apart from granting last-chance time-

extensions to various SR-Constituents, had also directed SRPC to monitor the status of

completion of PAR regularly in PCSC Meetings and submit bi-monthly Report to the

Commission confirming completion of Phase-I and Phase-II of PAR of the Constituents of

Southern Region.

In this regard, based on the information furnished various Constituents, a summary table

showing compliance status of various SR-Constituents as on 14.06.2018 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 66.66 Based on the status

furnished, timeline for

complying with the

remaining pending

recommendations (5 in

no.) is 30.06.2018

2 APGENCO

(Thermal) 30.07.2017 --- 83.33 Based on the status


complying with the

remaining pending


no.) is 31.08.2018.

3 APTRANS

CO 31.03.2017 --- 98.57 Based on the status

furnished, the lone


pending recomm-

endation is expected to

be completed by April

2018.

4 TSGENCO

(Hydel) 31.03.2017 31.03.2017 91.18 Based on the status


complying with the

remaining pending


no.) is 30.09.2018.

5 TSTRANS

CO 31.03.2017 31.03.2017 89.77 Based on the status


complying with the

remaining pending


no.) is 30.06.2018.

6 KPTCL 31.05.2017 31.05.2017 76.05 Based on the status


complying with the

remaining pending


no.) is 31.07.2018.

7 TANGEDC

O 31.12.2017 31.12.2017 77.77 Based on the status


complying with the

remaining pending


no.) is 30.09.2018.

8 TANTRANS

CO 31.12.2017 31.12.2017 58.33 Based on the status


complying with the

remaining pending


no.) is 31.12.2018*.

9 KSEBL 30.11.2016 31.12.2017 97.40 Based on the status


complying with the

remaining pending


no.) is 31.08.2018.

10 NPCIL

(MAPS) 31.01.2017 --- 88.89 Based on the status


complying with the

lone pending

recommendation is

September 2018. *TANTRANSCO has been asked to approach Hon’ble CERC to seek required time-extension.

28.2 It may kindly be noted that total compliance percentage of SR-Constituents in

completing Protection Audit Works as on 14.06.2018 stands at 84.65 %.

28.3 All above SR-Constituents are requested to kindly complete their respective pending

PAR at the earliest. IPP’s for whom there are pending PAR [viz., Spectrum PGL,


Konaseema GPL, APGPCL Vijjeswaram (Stage-I & Stage-II), & LANCO-Kondapalli

PL] are also requested to complete them at the earliest.

29. IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT

SYSTEM (PMS) FOR SOUTHERN REGION

29.1 Based on the approval of SRPC in the 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. This project was awarded through open

bidding process to M/s PRDC Pvt. Ltd. (PRDC) on 09.08.2017. The execution period for the

Project is about 18 months from the date of placement of LoA (also called “Effective Date”),

and is followed by an Extended Technical Services period of 5 years.

29.2 Details of the project implementation including Milestone-wise status is given at

Annexure–XXXVIII for kind reference.

29.3 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 dated 20.04.2018. Data collection by physical field visits of the stations in Tamil

Nadu, Puducherry, Kerala and Telangana has been undertaken by PRDC. Even though this

process had been completed, all the data sought as per stipulated formats for modeling 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.

29.4 Automated Fault Analysis System (AFAS) envisaged under PMS project was successfully

implemented for the 400/230-110 KV Palavadi SS (Pilot station) and was put under service

with effect from 18th

April 2018.

29.5 All SR-Constituents (Genco’s/ Transco’s/ LDC’s/ ISGS Utilities/ ISTS Utilities/ IPP’s/

other Generators/ etc.) are 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

Feb 2019.

30. COMPLIANCE STATUS OF NEW PROTECTION AUDIT RECOMMENDATIONS

30.1 As part of GSC (Task-II) under Package-A, protection audit check of 15 stations was

carried out by M/s Tractebel Engineering (TE) in Southern Region during the period,

December, 2015– July, 2016, wherein certain recommendations were also given for each

of these stations for compliance.

30.2 Subsequently, protection audit of various stations in SR has also been regularly conducted

by SRPC teams in line with Order dated 27.04.2015 of Hon’ble CERC in respect of

APTRANSCO Petition No.95/MP/2015 dated 09.04.2015. 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. Details of

stations audited during the period March, 2018 - June, 2018 are given below for kind

reference please:

30.3 Remarks given by the audit teams for the above stations are enclosed at Annexure – XXXIX

for perusal.

30.4 APTRANSCO, TSGENCO, TSTRANSCO, KPCL, KPTCL, KSEBL, TANTRANSCO,

Puducherry ED, NTPC (RSTPS), NPCIL (KGS), NLCIL, PGCIL (SR-I) & PGCIL (SR-II)

are 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

31.1 It is common knowledge that majority of the faults that occur on transmission lines are of

transient nature. Hence, provision of Auto-Reclosure certainly helps not only in preventing

forced outage of the subject transmission line, but also in averting cascade trippings, in some

cases, of adjacent transmission lines due to consequent over-loading.

31.2 Further, the 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.

31.3 In this connection, the logics for implementing A/R have been clarified in various PCSC

Meetings. Implementation status is being monitored periodically in the Meetings of PCSC.

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. It is brought to kind attention 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.

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)


31.4 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] are therefore requested to kindly take action accordingly to implement A/R on their

lines.

31.5 Latest status of A/R implementation by SR-Constituents on their 220 kV & above

transmission lines in SR-grid and the action plan proposed for implementing A/R where it is

presently not in service is proposed to be reviewed in the 76th

Meeting of PCSC scheduled to

be conducted on 26th

July 2018. The details are enclosed at Annexure – XL for kind

reference.

32. REVIEW MEETING ON COMPLIANCE OF PCSC RECOMMENDATIONS

32.1 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 Meetings of

Protection Coordination Sub-Committee (PCSC) of SRPC with a view to identify the 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 also being suggested/ recommended for compliance by concerned

Constituents. These recommendations, communicated vide Minutes of the Meetings, are

also being monitored for compliance by the concerned Constituents.

32.2 In this regard, latest status of implementation of PCSC recommendations pertaining to

various SR-Constituents for necessary compliance is enclosed at Annexure – XLI.

33. COMMERCIAL COMMITTEE ISSUES

33.1 Following issues are brought to the kind attention of TCC/ SRPC:

Transmission Charges pertaining to Kudgi STPS

Chairperson, SRPC vide letter dated 22.03.2018 (Annexure-XLII) had taken up the

issue regarding changing of the LTA quantum from 2392.49 MW to 2262 MW with

CMD, PGCIL.

Vide letter dated 28.06.2018 (Annexure-XLIII) 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 the same was again

forwarded.

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. This 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 ramp violation needs to be booked to the causer. (whichever

beneficiary avails URS) 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 respect of

Petition No 28/MP/2016, PPA wise DC has to be furnished by all ISGS. SRLDC

vide letter dated 28.05.2018 (Annexure-XLIV) had requested all 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

This 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 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 had 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 is Rs.66.32 Lakhs. MPPMCL had requested

APPCC to verify their claim.

MPPMCL has also submitted details of claimed 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 grave 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.

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 kindly 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

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


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 please:

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-8 107 23 13 0 0 9 1

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

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-XLV) had requested all states to review the identified feeders for UFR

and in case required, to have more number of radial feeders at lower voltage levels.

34.2.3 Review of UFR quantum and set points

NPC Secretariat vide letter dated 30.05.2018 (Annexure-XLVI) 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.

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

34.3.2 Summary for Southern Region (state-wise details are given in Annexure-XLVII) is

given in the Table below please:

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 kindly 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 are 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 need 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-XLVIII) had taken up the issue with

IPPs/MPPs. It was mentioned that generators may kindly ensure that the station

schedule considering all contracts shall not exceed the MW quantum of NOC given by

SRLDC for ensuring primary response as mandated in the Regulations.

34.3.8 SRLDC vide letter dated 29.05.2018 (Annexure-XLIX) 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.

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.

34.5 Sudden Change in Demand/Frequency Excursion (Clause 5.2 (j) of the IEGC)

Necessary action is kindly 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.

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 are kindly requested to ensure necessary

compliance.


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

ISTS connected IPPs TPCIL U1 & U2 (U2 Report to be analyzed); Coastal Energen U2;

IL & FS U1 & U2

For the following Units, PSS is to be tuned and SRT to be carried out / information not

available.

Entity Generating Stations/Units

APGENCO VTPS U5 & U6; Lower Sileru HEP U2 to U4

AP IPPs

TSGENCO


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; NTPC-Kudgi U2;

NLC-Neyveli TPS I Exp. U1 & U2 (SRT reports not submitted);

NPCIL- KGS U1, U3 & U4 ( Full Report not submitted for U4);

NPCIL-MAPS U1 & U2;

ISTS connected IPPs Coastal Energen U1; Lanco Stage II & III; SGPL-Nellore; SEL

U1 to U4; MEL U1 & U4

Generators to kindly initiate necessary action on the recommendations finalized in the

PSS meetings. In the 5th Meeting of Grid Study Committee held on 18th June 2018, it

was decided that a Committee would be constituted for PSS tuning at national level.

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 this 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 since this 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 could qualify to be declared as fuel shortage condition. 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 had recommended 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. 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 CEA, New Delhi with

a copy to SRPC. 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 the same to CEA.

CEA vide letter dated 10.04.2018 had sought 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.

Generation data of renewables as received from SRLDC had already been submitted

to CEA. All 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-L) 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

Issue regarding Kudgi DC being more than LGB target had been taken up by

Chairperson, SRPC with Chairperson, CERC vide letter dated 28.02.2018

(Annexure-LI).

KKNPP had closed both the 400 / 230 kV ICTs from 09.03.2018.

In the OCC Meeting, it had been agreed that availability certification of natural

inter-state lines and RPC certified intra-state lines would be carried out by SRPC.

Procedure for submitting the details had been circulated by SRLDC. All 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.

All states had been requested to furnish the element-wise outage details and

availability computation for natural ISTS lines and SRPC certified intra-state lines

(which have gone into POC mechanism) vetted by SLDC to SRLDC by 02nd

of

every month (for the previous month). 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-LII) 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.

SEIL request for enhancement of net exportable quantum from 1240 MW to 1254

MW was recommended by a group and noted in the 144th

Meeting of OCC.

In the OCC Meeting, it was reaffirmed that for shutdown of 400 kV bays (for 765

kV bays, NLDC approval was required) code would be exchanged with SRLDC,

though OCC approval would not be required.

KPTCL had been requested to study the high loading of 220 KV UPCL – Kemar

lines and take up reconfiguration works, if required.

Issue of frequent tripping of Konaje – Manjeswaram line on overload and the set

points were to be settled mutually between KSEBL and KPTCL.

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 in this regard 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.

Allocation of 50 MW to Telangana (SCR) and 100 MW to Tamil Nadu (SR) from

RGGPL was to be operationalized.

It was agreed that OCC approval for taking A/R in non-auto mode would not be

taken. However, a 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 if over voltage

continues to persist in the system. As and when, 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 of 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 conditions. The

remarks column of the respective line in the outage portal may be suitably

modified.

On the observation of NTPC Simhadri, a Study on loading of 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 within 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 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-LIII) had furnished the status report and

expressed concern on multiple tower collapses.

TSSLDC vide letter dated 09.05.2018 (Annexure-LIV) 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-LV) 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 would 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: 1,650)

In the 7th

Meeting of NPC 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 were to


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-LVI) had advised

TSGENCO to take up the work in compliance of CEA Regulations.

SRPC vide letter dated 28.06.2018 (Annexure-LVII) 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 kindly 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 Hon’ble 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...’

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 SR constituents jointly validated by SRLDC & SRPC Secretariat are

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.

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-LVIII) 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-LIX) had sought certain clarification wrt MNRE OM dated 01.03.2018.

Further, it had been 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 and other issues was held at NIWE, Chennai on 23rd

April

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.


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 Forum had 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 these recommendations, Chairperson, SRPC

vide letter dated 09.05.2018 (Annexure-LX) had taken up the issue of effective

implementation of provisions of CEA Regulations (including LVRT / HVRT) and other

security features by 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 in the region. 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.

PLF of Kaiga GS was 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.

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.

Ramagundam Stage-I & II, Ramagundam Stage-III, Neyveli Stage-II and Neyveli

TS-I Expn. had achieved PAF of more than 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 had got additional ramp of 262 MW/block

from ISG Stations.

36.2 Grid Highlights during February 2018

SR demand touched all time maximum of 45,325 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 47,210 MW

SR Consumption touched 1,080 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) OPGM 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) OPGM Fibre links (98.484 Km) were put under commercial

operation w.e.f 28.03.2018 by SR-II, PGCIL.

1x 125 MVAR 400kV 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 400/230kV 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 400/220kV 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 during this season.

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

commissioned on 19.05.2018 by APTRANSCO.

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


315 + 1 x 500 MVA.

220/132 kV SS Gunrock in Hyderabad District of existing 2 x 160 MVA was


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 400kV S/c Nelamangala – Hoody Transmission Line, 2 x 500 MVA,

400/230kV ICT’s 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 400kV 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 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 Feburary

2018 to May 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

Note: Highest & lowest figures for the month have been computed based on the daily

values.

36.7 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.

to

49.

7

49.7

to

49.9

49.9

to

50.0

50.0

to

50.05

50.05

to

50.20

More

than

50.20

Within

IEGC

range

49.9 to

50.05

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


During the period under review, caution / violation messages (Annexure-LXI) 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

are 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. 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-LXII.

Members are kindly requested to ensure payment, wherever due.

38. 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-LXIII). 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 Agenda.

39. RSD & TECHNICAL MINIMUM

39.1 KSEBL and TSTRANSCO had raised certain issues in respect of scheduling during RSD of

one of the units at Kudgi. These issues were discussed in detail in the OCC and CC

Meetings. NLDC vide letter dated 06.04.2018 (Annexure-LXIV) 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, concerns of the states (TS/Kerala) would

be communicated to Hon’ble CERC as they had sought comments on the TM / RSD

procedure and Compensation Mechanism. States had also been requested to furnish their

views to NLDC on TM / RSD Procedure. SRPC vide letter dated 16.04.2018 (Annexure-

LXV) had furnished its comments to Hon’ble CERC. Subsequently, SRPC vide letter dated

05.07.2018 (Annexure-LXVI) had taken up the concerns of SR states on RSD procedure

with Director (MO), POSOCO.


39.2 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

Corporate with NLDC / CERC.

40. 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-LXVII) had expressed concern about frequent changes in the annual outage

plan that had 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 this Outage Plan was also highlighted.

41. COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF

RENEWABLE ENERGY SOURCES

41.1 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

31.05.2018 Mapped I/C

Remarks

AP Wind: 3801.87/3965.87 MW (96.11%)

Solar: 2003/2209.78 MW (90.64%)

Total: 5662/6095.75 MW (94.15%)

Pending SCADA availability was for RE

connected distribution level and for which

action had been taken for compliance.

TS Wind: 100.8/100.8 MW (100%)

Solar: 3023/3257 MW (92.82%)

Total: 3123.8/3357.8 MW (93.03%)

Action for balance SCADA availability at

33 kV and below was being followed up

and notices had been issued.

KA Wind: 3504/3504 MW (100%)

Solar: 3079/3244 MW (94.91%)

Total: 6583/6748 MW (97.55%)

KE Wind: 16/59.3 MW (26.99%)

Solar: 71.18/90.858 MW (78.34%)

Total: 87.18/150.133 MW (58.07%)

TN Wind: 7988.96/8152 MW (98%)

Solar: 648/1918 MW (33.79%)

Total: 8636.96/10070 MW (85.77%)

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.


41.2 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-LXVIII). 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 would be

monitored and reported on a weekly basis. States had agreed to follow the same.

41.3 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.

42. SCHEDULING OF ANANTHAPURAMU ULTRA MEGA SOLAR PARK &

RAMAGUNDAM SOLAR PROJECT

42.1 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-LXIX) had communicated the activities of

the SPDs and SPPD.

42.2 Further, to have clarity on issues, SRPC vide letter dated 25.05.2018 (Annexure-LXX)

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 to Hon’ble

CERC.

42.3 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 due concurrence from CEA.

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

43.1 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. Terms of Reference

(TOR) was 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.

43.2 Grid Study Committee (GSC), which was constituted to facilitate the consultant's study/

analysis, had so far held five Meetings.

43.3 GSC in their 4th meeting held on 16.01.2018 (minutes issued vide NPC letter dated

01.03.2018 were circulated to SR-Constituents along with the minutes of PCSC-72 meeting

had accepted the following Reports:

Report of the Consultant M/s Tractebel Engineering on Task I & II under Package A.

Report of the Consultant M/s Powertech Labs Inc. on Task I, II & III under Package B.


43.4 GSC in the 5th

Meeting held on 18.06.2018 (minutes issued vide NPC letter dated 26.06.2018

would be circulated to SR-Constituents along with the minutes of PCSC-75 meeting) had

accepted the following report:

Report of the Consultant M/s Powertech Labs Inc. on Task IV, V & VI under Package B.

43.5 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.

44. OVR GRADING OF 400 KV AND 765 KV TRANSMISSION LINES OF SOUTHERN

REGION

44.1 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, 2017) had

been carried out. 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, 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. Above OVR gradings had also been

kept in SRPC Website for easy reference.

45. COMPLIANCE OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE

TRANSMISSION OF ELECTRICITY), REGULATIONS 2017

45.1 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-LXXI) 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. Further on the request of the constituents, a guiding Code for Cyber

Security audit has been prepared in consultation with the stake holders and circulated to all

the constituents.

46. SPECIAL MEETING ON THE TRIPPINGS OF POLES - 1 & 2 AT HVDC

GAJUWAKA SS OF POWERGRID (SRTS-I) – REG

46.1 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 Gazuwaka 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

46.2 The issue had also been raised in the Operational Feedback (Jan-Mar 2018) by POSOCO .

46.3 The Minutes of the Meeting were circulated vide SRPC letter dated 11.04.2018. PGCIL

(SRTS-I) is requested to kindly take appropriate action w.r.t. measures identified for

resolving issues w.r.t. Pole-1 & Pole-2 trippings.

47. SPECIAL MEETING ON THE PENDING PROTECTION ISSUES OF

PUDUCHERRY SUBSTATIONS

47.1 A Special Meeting is proposed to be held on 20th

July, 2018 at Puducherry ED HQ to

deliberate on all outstanding protection issues involving Puducherry substations. The

following issues are proposed to be discussed in that 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.

48. UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH

TRANSMISSION NETWORK

48.1 In the earlier Meetings it was noted that some 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.

48.2 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

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 6,050 MW ISTS connected wind bids (awarded-4,050 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, 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 (2,000 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.

49. PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS

49.1 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.

49.2 Concerned entities need to kindly initiate/continue necessary steps to ensure that

Patrolling and Maintenance is carried out regularly as per the Patrolling Guidelines.

50. 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

51. DATE & VENUE OF THE NEXT MEETING OF SRPC

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