southern regional power committee - karnataka€¦ · · 2017-10-23compliance of cea regulations...

Minutes of the 32nd Meeting of SRPC held on 22.08.2017

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

2. CONFIRMATION OF THE MINUTES OF 31st MEETING OF SRPC ..................................................................... 5

3. OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE ..................................................................... 5

4. MEMBERSHIP TO RPC ..................................................................................................................................... 8

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

AMENDMENT RULES, 2015 ............................................................................................................................ 9

6. RELIABLE COMMUNICATION SCHEME UNDER CENTRAL SECTOR FOR SOUTHERN REGION ....................... 11

7. TECHNICAL COMMITTEE FOR IMPLEMENTATION OF FRAMEWORK ON RENEWABLE AT STATE LEVEL ..... 12

8. TECHNICAL COMMITTEE CONSTITUTED BY CEA .......................................................................................... 12

9. OPTIMUM HARNESSING OF RE IN SOUTHERN REGION ............................................................................... 13

10. COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF RENEWABLE ENERGY SOURCES ........ 18

11. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE ...................................................... 20

12. UPCOMING TRANSMISSION SYSTEM ........................................................................................................... 21

13. UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH TRANSMISSION NETWORK ............. 34

14. REQUEST TO ISSUE CERTIFICATE FOR CLAIMING ADDITIONAL ROE ............................................................ 41

15. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ................................................................ 42

16. NEW PROJECTS OF STATE SECTOR & IPP ..................................................................................................... 45

17. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY .................................................................... 46

18. INCLUSION OF DRAWAL OF MAHE IN REA ................................................................................................... 47

19. ISSUES IN RESPECT OF NPCIL ........................................................................................................................ 48

20. COMMUNICATION REQUIREMENT DURING NATURAL DISASTERS ............................................................. 51

21. STATUS OF GENERATION IN ISGS ................................................................................................................. 52

22. REVIEW OF ULDC / SCADA/COMMUNICATION ............................................................................................ 52

23. URTDSM (PMU) PROJECT IN SOUTHERN REGION ........................................................................................ 55

24. SCHEDULING OF WIND & SOLAR GENERATING PROJECTS HAVING CAPACITY OF 500 MW AND ABOVE ... 57

25. TTC/ATC ........................................................................................................................................................ 58

26. METHODOLOGY FOR CERTIFICATION OF INTRA-STATE TRANSMISSION LINE ............................................. 61

27. EMERGENCY RESTORATION SYSTEM (ERS) .................................................................................................. 61

28. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR ............................................................. 63

29. OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS ....................................................... 67

30. NON-AVAILING OF OCC APPROVED SHUTDOWN ........................................................................................ 68

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

32. SPARE ICT AND REACTOR PLACEMENT AND USAGE PROCEDURE ............................................................... 71

33. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION .............................................................................. 71


34. IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT SYSTEM (PMS) FOR SR ........... 87

35. POWER SYSTEM ANALYSIS GROUP (PSAG-18) MEETING HELD ON 4TH JULY, 2076 AT 400/ 220/ 66 KV

HOODY SUBSTATION OF KPTCL IN THE CONTEXT OF FREQUENT TRIPPING OF 400/ 220 KV ICT’S ............. 89

36. PROTECTION AUDIT OF SUBSTATIONS IN SR CONDUCTED DURING MARCH – AUGUST, 2017................... 89

37. AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE TRANSMISSION LINES OF SR .................. 90

38. IMPLEMENTATION OF LINE DIFFERENTIAL PROTECTION (LDP) IN NELLORE & SIMHADIRI COMPLEXES .... 92

39. PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS ....................................................... 93

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

OTHER PROVISIONS OF CEA/CERC REGULATIONS ....................................................................................... 94

41. PENDING IMPLEMENTATION OF RECOMMENDATIONS OF PCSC OF SRPC ................................................. 94

42. COMMERCIAL COMMITTEE ISSUES .............................................................................................................. 94

43. MONITORING OF SCHEMES FUNDED FROM PSDF ....................................................................................... 96

44. SCHEDULING OF KAMUTHI SOLAR PARK ...................................................................................................... 96

45. AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM .......................................................................... 97

46. GRID OPERATION ......................................................................................................................................... 98

47. CONGESTION RELATED ISSUES ................................................................................................................... 106

48. REIMBURSEMENT OF SRPC EXPENDITURE ................................................................................................. 106

49. STATE-WISE ALLOCATION OF 540 MW POWER FROM RGPPL TO RAILWAYS............................................ 106

50. ADVANCE INTIMATION REGARDING FIRST TIME SYNCHRONIZATION OF TRANSMISSION ELEMENTS ..... 109

51. FREQUENT FAILURES OF TRANSMISSION LINE TOWER OF VOLTAGE LEVEL 220 KV & ABOVE ................ 109

52. IMPLEMENTATION OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE TRANSMISSION OF

ELECTRICITY) REGULATIONS, 2017 ............................................................................................................. 110

53. OVR GRADING OF 400 KV AND 765 KV TRANSMISSION LINES OF SOUTHERN REGION ............................ 110

54. APPRAISAL REPORT ON KSEBL’S REVISED PSDF PROPOSAL ....................................................................... 110

55. STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY RESOURCES INTO THE GRID ....... 111

56. NON-ADHERENCE TO THE MAINTENANCE SCHEDULE - OVERHAULING OF TALCHER STAGE II U4 .......... 111

57. OUTSTANDING DUES FROM TSDISCOMS TO APGENCO ............................................................................ 112

58. URS ALLOCATION TO NON-BENEFICIARY ................................................................................................... 112

59. CONCLUSION .............................................................................................................................................. 112

60. DATE & VENUE OF THE NEXT MEETING OF SRPC ....................................................................................... 112


SOUTHERN REGIONAL POWER COMMITTEE

BENGALURU

MINUTES OF THE 32nd

MEETING OF SRPC HELD ON 22.08.2017 AT

THIRUVANANTHAPURAM

1. INTRODUCTION

1.1 The 32nd

Meeting of the Southern Regional Power Committee (SRPC) was held on 22nd

August

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

1.2 Team KSEBL welcomed the respected dignitaries to the 32nd

SRPC Meeting being held at

Kovalam, Thiruvananthapuram, also known as „Paradise of South India‟.

1.3 Dr K Ellangovan, CMD, KSEBL welcomed Chairperson, SRPC, Member Secretary, SRPC and

distinguished delegates to the 32nd

Meeting of SRPC. He noted that the TCC Meeting had been

well attended and the deliberations had been fruitful. The delegates of the TCC would

acknowledge that the Meeting had been very useful in sorting out various issues of significance

between member states. He stated that it was a pleasure to host this Meeting with all Members

kindly accepting to come to Thiruvananthapuram. This Meeting would be discussing some vital

issues which are now being faced. It was the view of KSEBL that SRPC Meetings have been

extremely beneficial to place ones views on the table, so that the same get acknowledged not only

in SRPC but at the highest level. SRPC has been very useful to the State of Kerala being tucked

away from other states in respect of geographical location. CMD, KSEBL acknowledged the

contribution of SRPC in various matters. He welcomed Shri D Prabhakar Rao, Chairperson,

SRPC and stated that he has been very active, keen and methodical. He was certain that SRPC

under his able Chairmanship would find solutions to some of the difficult problems being faced by

the SR power sector. He welcomed the Members who had joined for the SRPC meeting - Shri

Jawaid Akhtar, MD, KPTCL, Shri G Kumar Naik, MD, KPCL, Shri K Vijayanand, CMD,

APTRANSCO, Shri A Gopal Rao, CMD, TSTNPDCL, Shri U K Verma, ED, NLDC, Shri V

Thangapandian, Director (P), NLC and Shri R K Singh, ED (SR-II), PGCIL. This Meeting was

also being attended by several important functionaries of Government, State Government, other

utilities etc. He thanked his entire team for their wonderful efforts in organizing this Meeting. He

hoped that all current issues would be deliberated and wished fruitful deliberations.

1.4 Shri S R Bhat, Member Secretary, SRPC welcomed all the esteemed Members to the 32nd

SRPC

Meeting. He welcomed Chairperson, SRPC & CMD, TSTRANSCO to the Meeting and requested

him to kindly chair the same. He also thanked CMD, KSEBL and the entire team for the

outstanding arrangement made for both the Meetings.

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

all attending the 32nd

SRPC Meeting. He added that the 30th

TCC and 31st SRPC Meetings were


conducted on 24.02.2017 and 25.02.2017 at Bengaluru and Minutes were communicated by MS,

SRPC on 12.04.2017 and 11.05.2017 respectively. Southern Region has been in the forefront in

maintaining grid discipline and always takes lead in implementing CERC/CEA/MoP guidelines.

Main challenge confronted by SR is regarding handling of Renewable Energy. SR was leading in

RE front with a target of 60 GW by 2022 as against all India target of 175 GW. It was heartening

to note that SR had already achieved 22 GW of RE. To address this issue, a Special Meeting of

SRPC was conducted at Hyderabad on 31.07.2017, wherein it had been agreed in principle to go

ahead with the Overarching Agreement among Southern States for mutual exchange of power for

better harnessing of RE to minimize the balancing resources. Further, a Working Level Committee

had been formed to work out the modalities. Accordingly, the issue of cooperation among

Southern States was further discussed during the Working Level Committee Meeting through VC

on 04.08.2017 and a few modifications had been incorporated in the Agreement. Finally, the

Overarching Agreement for regional cooperation for better harnessing of RE without endangering

the grid security had been concluded. He placed on record appreciation for concluding this

outstanding concept by SR entities for harnessing maximum RE with least cost, which had also

been appreciated by CEA and MoP. He added that it was time to address the Regulator to reduce

clearing time for power exchange market transactions to 4 time blocks. This would help in quicker

exchange of power since presently time for transacting power through exchange was around 3

hours. Another challenging issue to be stressed was readiness of downstream network by SR states

to match the interstate transmission system. It was very important that state transmission utilities

plan the network well in advance and complete downstream 400 kV and 220 kV sub stations and

lines for evacuating the power from the ISTS projects soon after their commissioning. It was also

observed that there was under utilization of inter-regional links such as 765 kV Angul-Srikakulam

and 400 kV Jeypore-Gazuwaka. All concerned states and CTU should take proactive steps for

utilization of inter-regional links for evacuating of bulk power to the maximum extent possible for

benefit of all stakeholders. He requested all states and delegates to express their views and

opinions on the agenda points which would help take timely decisions for expediting various

projects/schemes in the interest of the region. He hoped that Southern Region would continue to

take lead role in the country by means of more proactive initiatives for betterment of power sector

in future too. On behalf of SRPC, he conveyed sincere thanks to Dr Ellangovan, CMD, Directors

and other officials of KSEBL for making excellent arrangements for the Meeting.

1.6 SRPC welcomed the following new Members:

Shri H Y Dora, CMD, APSPDCL

Shri A Gopala Rao, CMD, TSNPDCL

Ms Ruby Srivatsava, Director (F), NPCIL

Shri M Prabhagar, CEO, NTPL


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

Shri M M Nayak , CMD, APEPDCL

Shri G Raghuma Reddy, CMD, TSSPDCL

Shri Preman Dinaraj, Director, NPCIL

Shri R Parthasarathy, Head, Bangalore Office, UPCL

Shri A R Neelakanta Pillai, CEO, NTPL

1.7 Agenda was taken up for discussion.

2. CONFIRMATION OF THE MINUTES OF 31st MEETING OF SRPC

2.1 Minutes of the 31st Meeting of SRPC held on 25

th February 2017 at Bengaluru was circulated vide

letter dated 11th

May 2017.

2.2 Minutes of the Meeting were confirmed.

3. OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE

3.1 POSOCO had carried out operational analysis of various hydro stations in the country. A Report on

Operational Analysis for Optimization of Hydro Resources & facilitating Renewable Integration in

India was also prepared. It was observed by POSOCO that a number of hydro stations particularly in

the state sector are not being operated in peaking mode. MoP had constituted a Sub-Committee

under Chairperson, CEA to study and recommend individual hydro power stations which can be

operated to achieve peak load capacity. This Sub-Committee had held three Meetings with

concerned Hydro generating stations and concluded that there was scope of about 2,000 MW

additional power generations from hydro station during peak hours. CEA vide letter dated

18.07.2017 (Annexure-II) has advised that the above issue be discussed in the TCC/RPC Meeting

in all the regions. CEA had also advised that the matter of utilization of hydro stations in peaking

mode be made an Agenda Point for discussion in the monthly OCC Meetings while discussing

operational planning for the month ahead and analyzing the operation in the previous month.

3.2 POSOCO vide letter dated 21.07.2017 (Annexure-III) had furnished an agenda item on

„Operational analysis of Hydro Power Stations‟. Issue had been discussed in detail in the 134th

Meeting of OCC held at Neyveli on 11th

August 2017 (Summary given as Annexure-IV).

TCC deliberations

3.3 The issue had been deliberated in detail in the TCC and the following was summarized:

Presentation made by SRLDC/NLDC is given at Annexure-V.

It was felt that hydro generation is already being optimized by SLDCs.

Feedback of the 134th

Meeting of OCC has been passed on to NLDC for kind consideration.

NLDC stated that the feedback of these Meetings would be considered.

Suitable Market mechanism/incentive scheme needed to be in place for the purpose of any

hydro optimization.


SRPC deliberations

3.4 MS, SRPC informed that the issue had been deliberated at length in the TCC and the following

was noted:

Efforts of POSOCO in preparation of the questionnaire and analysis. POSOCO had come out

with a nice report which was well appreciated. POSOCO had put in lot of effort, time and

energy in preparation of this report. In a nutshell, POSOCO had analyzed peaking, ramping

capacity utilization factor and also identified constraints in optimal usage with flexibility based

on all India peak demand curve. On various parameters the analysis had been carried out. They

had also suggested multipart tariff for hydro stations for better utilization.

TSTRANSCO had stated that hydro utilization also depended on irrigation requirements and

LGB management of the control area. Dispatch based on national peak, ramp rates etc may be

considered only with proper market mechanism in place. Margins are kept to meet RE and load

variations.

KSEBL had stated that final report had not been shared and SLDC had not been consulted

appropriately. Hydro in merit order is considered based on price of the replaced energy in the

entire water cycle year and not merely on the basis of the cost. Hydro generation was also

being modulated based on power exchange rates.

TANTRANSCO had stated that this was 2nd

year of poor monsoon and storage was only

20-25 %. Study based on peak for last one year data could not be conclusive. 6,000 MW of RE

was to be balanced and available hydro was also limited. Operation of hydro in NR/NER

cannot be compared with Hydro operation philosophy of SR.

KPTCL had stated that hydro was also required for grid security, deviation management, fall

in generation due to outages, RE withdrawal and was also based on seasonal requirement.

Hydro generation was being maximized during the period January to April since the power

rates were higher.

APTRANSCO had stated that hydro generation was also based on irrigation and drinking

water requirements.

It was felt that hydro generation was already being optimized by SLDCs keeping in view

specific requirements of the respective control areas.

A clear Market Mechanism was required to be introduced which may incentivize hydro

support for peaking, ancillary services etc.

3.5 CMD, TSTRANSCO pointed out that water was very precious in various aspects. Water usage

was with different objectives in various states. In AP and TS, hydro projects are multipurpose

projects. Though hydro generation in TS was designed for around 3,500-4,000 MUs, in 2015-16

there was generation of only 269 MUs. There were several uncertainties and as expressed by the

states, hydro generation was already being optimized. Srisailam LB was being utilized for

condenser mode, pump mode besides generation. Final decision of operating hydro should be left

with the concerned States where projects are located.

3.6 ED, NLDC stated that the views of the forum are well acknowledged and hydro generation in SR

was being optimized. Only requirement of NLDC was that keeping in view daily allocated

quantum of energy for hydro, considering all constraints (agricultural/drinking) support could be


extended to meet peak and balance could be utilized to meet other requirements. All SR states

were purchasing power through exchange. Price of power during peak was higher, and thus it

made economic sense to utilize higher hydro during peak hours. Price of power was generally

following the load curve, it was up to Rs 7-8 during peak and going below Rs 2 during off peak

hours. All over the world similar market has evolved where peak rates are higher than off peak

rates. This would contribute to economic benefits by means of saving for the states.

3.7 CMD, APTRANSCO noted that in respect of SR states, the presence of renewable was quite

significant. Historically, hydro was being utilized to meet the peak while other generation such as

Thermal, Solar etc was being utilized during day. Hydro optimization may not be required to be

revisited for any further refinement.

3.8 ED, NLDC informed that out of 150 hydro stations (equivalent to 32 GW which is around 80 %

of the total population) it was found out that there were only 43 stations where peaking

optimization was required. In SR, there were around 18 stations and in these stations the

generation pattern could be studied and further peaking support could be extended.

3.9 MS, SRPC stated that the suggestion appeared to be for all India peaking support while each state

was an individual control area as per Grid Code. There would be reasons for specific hydro

generation pattern through the day. Since hydro generation was also based on storage content,

average values may not work out. Based on storage, market, RE variability, load variability,

irrigation requirements etc the hydro optimization is being carried out.

3.10 CMD, KSEBL opined that the consultation process by POSOCO with states was not as much as it

should have been. He was personally not aware of this study. Kerala‟s load curve was different

from that of other states. KSEBL had optimized hydro power in such a manner that the cost of the

overall power gets optimized. Dams were not only for hydro generation, but were also being

utilized for irrigation and drinking water requirements. As noted in the Assembly, drinking water

requirement was of major concern followed by that of power. The compulsions for water

utilization were different from state to state. Kerala‟s hydro was being utilized during peak beside

the must run hydro during the day. Further optimization may not be possible. State wise hydro

optimization within the control area constraints was a better approach rather than painting an all

India picture. POSOCO had earlier brought out analysis of demand, load curve etc for 8 years

which was Volume-1. Subsequently, state specific analysis was carried out which was Volume-2

and similar approach needed to be adopted now. In the State related chapters, critical appraisal

needs to be carried out.

3.11 MS, SRPC stated that critical state-wise analysis may bring out the real optimization. Further, in

NR & NER, many of the hydro units were central sector units, while in SR all were state owned.

3.12 ED, NLDC stated that unit wise analysis has already been carried out and only after detailed study

43 stations had been identified. Ancillary services market for hydro was under consideration and


they had already moved the matter before Hon‟ble CERC. Tariff design may need to be looked

into by SERCs in line with that for central hydro units.

3.13 MD, KPTCL stated that the crux of the issue has already been highlighted by SRPC. For the

POSOCO report, a lot of statistics had been collected. But it was quite apparent that there was no

detailed discussion and interaction with state utilities during finalization of the report. The report

might have assumed, as evident from the deliberations the present scenario and it might not have

considered requirement of the state vis-à-vis target of 175 GW of RE by 2022. Like TN,

Karnataka also may find it difficult to manage the RE. In Karnataka, reserves had been declining

since last three years - from 55% to 44% while this year it was at 41%. The optimization in

totality could only be appreciated through extensive interactions with SLDC on a day-to-day

basis. With this target it would be rather difficult to manage the grid/RE in the next 2-3 years.

States may not have necessary resources and thus GoI may need to step in and create a scheme at

national level. POSOCO should have comprehensively discussed this matter with states before

finalizing the report. The resources belonged to the states and were to be utilized by them, in tune

with the federal structure.

3.14 MS, SRPC informed that a Committee headed by Member (Planning), CEA had been constituted

by MoP and the Committee was already looking into various issues. Region wise/ joint meetings

had been conducted and they are in process of finalizing the Report. Issues relating to Balancing

requirement, ramps etc had been covered in the Report.

3.15 ED, NLDC stated that they were open to suggestions and would interact with each state

individually. He added that there were three types of reserves- Primary, Secondary and Tertiary.

CERC orders specified quantum to be maintained by the state utilities and at the national level.

NLDC was considering monitoring of the reserves w r t the stipulated quantity.

3.16 Chairperson, SRPC concluded that it was almost unanimous that the final decision on hydro

optimization should be left to the states. As suggested by CMD, KSEBL, state-wise analysis for

hydro operation could be carried out by POSOCO in coordination and close consultation with

SLDCs.

4. MEMBERSHIP TO RPC

4.1 Withdrawal of Membership from SRPC

M/s Lanco Kondapalli Power Ltd (LKPL) vide letter dated 25.07.2017 (Annexure-VI) had stated

that there is no power generation from their plant since last nine months and also no visibility of

generating power in the near future under the present circumstances. In light of this, they would be

unable to contribute in respect of expenditure of SRPC Secretariat and hence are withdrawing their

Membership from SRPC. They would consider availing Membership with SRPC, as and when,

their plants become operational.


TCC deliberations

This issue would be deliberated in the SRPC Meeting.

SRPC deliberations

SRPC agreed for withdrawal of the Membership of LKPL.

4.2 Trader Membership

MS, SRPC informed that CEA vide letter dated 03.08.2017 (Annexure-VII) had communicated the

Membership of JSW Power Trading as Trader Representative in SRPC for 2017-18.

SRPC deliberations

COO (Trading), JSWEL stated that JSW Power Trading had been inducted as trader representative

in SRPC for the current financial year. But already half of the financial year was over and the

objective of representation was lost. CEA may kindly communicate the Membership in March /

April each year so that the concerned Trader is associated with respective RPC for the entire year.

Since the Membership was communicated in August they are not willing to accept the Membership

for the current year.

It was agreed that this issue could be brought to the notice of CEA.

5. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER

ENVIRONMENT (PROTECTION) AMENDMENT RULES, 2015

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

installed from 01.01.2017 onwards) as per Environment (Protection) Amendment Rules, 2015 were

notified by Ministry of Environment, Forest & Climate Change (MOEF & CC) (Gazette Notification

dated 07.12.2015). MOEF guidelines had classified thermal generators into three categories with

different norms. The three classes were - prior to 31st December 2003, 1

st Jan 2004 to 31

st December

2016 and beyond 1st

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.

5.2 CEA, New Delhi vide letter dated 22.12.2016 had intimated that a Committee headed by

Chairperson, CEA had been constituted by Ministry of Power; Govt. of India for preparing phasing

plan for implementation of new environmental norms issued in December 2015 by MOEF &CC

with regard to SPM, SOx & NOx emissions. 1st & 2

nd Meetings of this Committee were conducted

on 21st October 2016 and 13

th December 2016 respectively. Accordingly, a Meeting was conducted

on 12th

January 2017 at SRPC, Bengaluru to deliberate on status and also firm up Phasing Plan.

(Minutes of the Meeting available on SRPC website).

5.3 The following had been noted in earlier Meetings:

SRPC had noted the requirements for necessary compliance.


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

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

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

up the works was quite exorbitant. All entities could therefore suitably take the request for time

extension with the concerned Authorities.

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

stipulated revised environmental norms.

5.4 Subsequently, CEA had firmed up the FGD phasing plan and uploaded the same on its website.

Later, a Meeting to firm up phasing out plan for thermal unit which do not have space for FGD was

held on 25th

March 2017 (Minutes available at SRPC website). Updated Plan for FGD

implementation with respect to SR Units with confirmation/comments is given at Annexure-VIII.

The Phasing Out Plan is given at Annexure-IX. However, confirmation/comments are awaited from

most of the generators.

5.5 Chairperson, SRPC vide letter dated 24th

May 2017 (Annexure-X) 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.

5.6 The following was noted in the TCC Meeting:

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

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

for FGD and the issue would be reviewed/decided in the next Board Meeting. AP was in

discussions with M/s BHEL and its team had also visited the power stations. There were issues

with regard to limestone availability and also disposal of gypsum. Phasing out was also to be

considered based on the commissioning of new 800 MW units at Krishnapattnam & Vijayawada

(both expected in 2019) and overall energy security of the state.

TSGENCO had expressed concern over space constraints for FGD installation in some of the

plants and over the huge expense to GENCOs and consequent implications on tariff.

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

been taken at site. Based on the results, the type of FGD etc would be suggested by Consultant.

NLC was seriously pursuing this matter and a decision would be taken after the Consultant‟s

report is made available.

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

Action was to be initiated to adhere to the FGD Plan and also Phasing Out Plan finalized by

CEA/SRPC.

After deliberations, TCC had recommended that Chairperson, SRPC may be kindly requested to

once again take up the issue of funding (PSDF/any other fund) with Ministry of Power, for

meeting the environment norms.

SRPC deliberations

5.7 Director (P), NLC informed that the readings had been taken by the Consultant. Though space

constraints were there, but the report was awaited. The consultant would be suggesting the way

forward and a call would be taken after that.

5.8 MS, SRPC stated that the basic premise of earlier CEA report was based on inputs furnished by


generators on the space for FGD. Based on inputs furnished by NLC, the units of TS-II had been

identified for phasing out. The NLC Report may need to be expedited and CEA was required to be

informed accordingly.

5.9 Director (P), NLC stated that the report was expected in about 1-1½ month and the status would

thereafter be communicated to CEA.

5.10 CMD, TSTRANSCO stated that the MOEF guideline was to be implemented but the financial

support should also be considered. Some support through PSDF or special funds was required from

GoI. The impact to meet norms was around Rs 1 crore/MW, it would be burden to the state utility

which would have to be passed on to the consumer. Space constraints for FGD in certain cases were

also to be considered.

5.11 MD, APGENCO noted that already thermal power was getting costly as could be seen from Kudgi.

Further investment to the tune of Rs 1-1.5 crore/MW to meet environment norms would be difficult

for the State Government. The burden would automatically arise and it would thus be difficult for

the generator to be economically viable. A resolution could be passed to request GoI to support the

generators in meeting the environment norms. At the time when the plants were designed and

constructed, the norms and costing were different and the Regulator had accordingly fixed the costs.

Chairperson, SRPC could take up the issue with Secretary, MoP to consider some sort of financial

support be it from PSDF, NCEF or any other fund.

5.12 MD, CEPL stated that from IPP point of view also, it was very necessary that some sort of funding

was required. The cost would be Rs 1-1.5 crore/MW and it could be extremely difficult to pass it on

to the tariff.

5.13 Chairperson, SRPC stated that a specific mention of IPP cannot be made and a general appeal to GoI

would be made.

5.14 It was agreed that Chairperson, SRPC would take up the issue of financial support through PSDF,

NCEF or any other fund for the generators to meet the revised environment norms.

5.15 Generators were kindly suggested to keep CEA apprised of developments with regard to

FGD/Phasing Out plan. Appropriate action needs to be initiated as per the FGD/Phasing Out plan

finalized by CEA.

6. RELIABLE COMMUNICATION SCHEME UNDER CENTRAL SECTOR FOR

SOUTHERN REGION

6.1 POWERGRID vide letter dated 4th

August 2017 (Annexure-XI) had stated that in the 31st Meeting

of SRPC, approval had been accorded for reliable communication scheme of 5,406 kms of OPGW

based communication network at an estimated cost of Rs.135.17 crores. It is now intimated that the

estimated cost comes out to Rs.171.16 crores. However, actual cost shall be discovered only after

the bidding process. It had also been intimated that tender activities has been initiated as per DPR.

6.2 SRPC noted the above.


7. TECHNICAL COMMITTEE FOR IMPLEMENTATION OF FRAMEWORK ON

RENEWABLE AT STATE LEVEL -FOR

7.1 FOR vide their communication dated 02nd

May 2017 had informed that a Technical Committee under

the Chairmanship of Member, CERC had been formed at the direction of Forum of Regulators

(FOR). This Committee comprises of Technical Members of State Commission of renewable rich

States, viz. Tamil Nadu, Gujarat, Rajasthan, Maharashtra, Andhra Pradesh, Karnataka and Madhya

Pradesh. The objectives of the Committee include facilitating implementation of Regulations for

Forecasting, Scheduling and Deviation Settlement at the State level, implementation of ABT

framework and Ancillary Services in member States, among others. The Committee in its eleventh

Meeting held in Chennai on 28.03.2017 had felt that with increasing penetration of Renewable

Energy (RE) in the backdrop of GoI‟s 175 GW RE target, increasing inter-state transmission of

power and commitment of 24x7 Power to All, regional cooperation for optimum utilization of

generation resources had become critical. Further, it had been decided that Sub-Groups be

constituted in Northern Region, Western Region and Southern Region (three RE rich regions)

headed by the Member Secretaries of the respective Regional Power Committees (RPCs) to examine

this issue. This Sub-Group shall inter-alia examine feasibility and modality of cooperation among

states in the respective region for ensuring optimum utilization of generation resources with least

cost options for balancing across the region.

7.2 Subgroup Meeting of SR under Technical Committee for Implementation of Framework on

Renewable at State Level was conducted in SRPC, Bengaluru on 07th

June 2017. Recommendations

(Annexure-XII) of this Sub Group had been submitted to the Technical Committee.

7.3 TCC deliberations

MS, SRPC had informed that the Sub Group had submitted certain recommendations which also

included Overarching Agreement for STOA under MCP /Swap, Separate Control Area for RE

and Sale of URS through Generator (for firmness) which would be examined by the Committee.

Also there was another Meeting held in CERC on 18th

August 2017.There was discussion about

another intra-day product through PX, which would not be as rigid as presently available

products.


8. TECHNICAL COMMITTEE CONSTITUTED BY CEA

8.1 A Technical Committee had been constituted by CEA for study of optimal location of various types

of balancing energy sources/energy storage devises to facilitate grid integration of Renewable

Energy Sources and associate issues. Subsequently a Meeting of Sub- Group of Southern Region

formed under the Technical Committee was conducted on 24th

March 2017 with participation from

CEA and the Minutes of the Meeting issued on 20.04.2017 is at Annexure-XIII. The second

Meeting of the Technical Committee was held at Chennai on 09.05.2017. The final meeting was

held at New Delhi on 29.06.2017. The Minutes of the Meeting are available on website of CEA.


8.2 TCC deliberations

MS, SRPC informed that in the Committee Meeting, a new concept of net DSM had been

discussed through which a state may get insulated from vagaries of RE. DSM of the Control Area

may be arrived excluding the Deviation of the RE generators.


9. OPTIMUM HARNESSING OF RE IN SOUTHERN REGION

9.1 Follow up of MoP meeting / Special TCC

9.1.1 A Meeting was held on 10th

February 2017 in MoP on matters relating to optimum harnessing of

Renewable Energy Integration in SR without endangering Grid Security. A number of actionable

points had been finalized in that Meeting and time lines for compliance of the same also had been

specified. SRPC vide letter dated 02.05.2017 (Annexure-XIV) had requested the concerned

utilities that the matter may kindly be arranged to be reviewed and urgent action arranged

wherever necessitated. A Special TCC Meeting was also convened on 20th

May 2017 (Minutes at

Annexure-XV) in SRPC, Bengaluru.

9.1.2 SRLDC had conducted a Capacity Building Workshop on STOA Procedures on 19th

May 2017 in

compliance. A Special Meeting of SRPC Members of the constituent states was also held on 31st

July 2017 at Hyderabad. Based on the discussions in the Hyderabad Meeting, a draft Overarching

Agreement had been prepared and circulated. It had been proposed to sign the Overarching

Agreement in SRPC Bengaluru on 17th

August 2017.

9.1.3 TCC deliberations

TANGEDCO vide letter dated 17.08.2017 (Annexure-XVI) had informed that rate of energy of

power to be exchanged as per item no. 7 was not viable to TANGEDCO. SRPC in its reply vide

letter dated 18.08.2017 (Annexure-XVII) had again requested TANGEDCO to kindly sign the

Agreement.

MS, SRPC had informed that the Overarching Agreement had been signed between APPCC,

TSDISCOMs & KSEBL on 17th

August 2017. He had thanked the utilities for their kind

cooperation in this regard.

PCKL had stated that they would communicate their views in the SRPC Meeting.

TANGEDCO had stated that they would consider signing the Agreement under Swap with

mutually agreed rates for the residual energy.

In respect of SAMAST implementation, the following had been noted:

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

to NLDC for funding. It was of concern that the amount approved was only about 1/5th

of the

estimate.

TSTRANSCO had also endorsed the views of APTRANSCO and stated that NLDC should

take lead and approve higher funds. They had submitted estimate of Rs 85 crores and in case

much lower funds are approved, it may not encourage entities to take up the project in a time

bound manner.

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

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

of the month.


TCC had urged concerned entities to initiate action to complete pending points as noted in the

Special TCC Meeting held on 20.05.2017. Implementation of SAMAST was targeted to be

completed by December 2017. NLDC was requested to kindly look into the possibility of higher

fund approval for the proposals under SAMAST. Demand and RE forecasting / scheduling was

also to be undertaken by states on a priority basis.

SRPC deliberations

9.1.4 MS, SRPC thanked Chairperson, SRPC for his proactive leadership in enabling conclusion of the

Overarching Agreement in the Meeting held on 31.07.2017.

9.1.5 Chairperson, SRPC requested KPTCL & TANGEDCO to also sign the Overarching Agreement. In

this Agreement there was no commitment on any state. This Agreement could be more

advantageous to TN on account of the high RE penetration.

9.1.6 MD, KPTCL informed that they were ready to sign the Agreement.

9.1.7 CMD, KSEBL enquired about the mutually agreed rates being requested by TN. He added that

KSEBL had been of the view that TN would participate and surplus power would be availed. He

requested TN to kindly consider signing the Agreement. Since monsoon was below par, RE

potential in the region should be exploited to the maximum. TN could weigh the cost of RE

absorption and the likely benefits of trade and take a judicious decision.

9.1.8 MS, SRPC clarified that the option of mutually agreed rate under swapping was only in respect of

residual energy under swap. He suggested that states could kindly use the mechanism for RE

Integration and other contingencies and put the system in place. He noted that initially all

initiatives were with the premise that TN was having constraints at times, for absorption of RE

power in full.

9.1.9 Director (O), TANTRANSCO informed that within one weeks‟ time they may sign the

Agreement. Approval of State Government/ Management was required for this purpose. They

would consider signing the agreement under Option 2 (swap).

9.1.10 CMD, APTRANSCO stated that TN should also come forward to sign this Agreement, especially

since there were no commercial implications.

9.1.11 NLDC was kindly requested to favorably consider approval of the SAMAST DPRs.

9.1.12 APTRANSCO informed that while DPR of Rs 57 crores, only Rs 11 crores had been approved.

The component relating to metering and CT/PT had not been approved and revised DPR had been

requested.

9.1.13 CMD, TSTRANSCO also raised concern and stated that releases are relatively very less and

requested NLDC to look into this aspect favorably.

9.1.14 ED, NLDC assured that the DPRs under SAMAST would be possibly relooked. For reliable

communication the grant has been raised to 50% which was earlier 30%. Many schemes had been

approved by Monitoring Committee, but the utilities had not come forward to sign the Agreement.

9.1.15 MS, SRPC observed that pace of utilization of funds of sanctioned schemes may need acceleration.


NLDC had been regularly taking review meetings for appraising Ministry. There was a general

perception that utilization was not taking place as desired.

9.1.16 Chief Engineer, NPC stated that utilization was an area of concern. Out of Rs 421 Crores for

Kerala only Rs 23 Crores had been availed. For Karnataka out of Rs 17.9 Crores only Rs 8.7

Crores has been availed, Out of Rs 255 Crores for AP, only Rs 11 Crores had been availed while

in case of Telangana out of Rs 108 Crores only Rs 24 Crores had been availed. In case of Tamil

Nadu out of Rs 304 Crores Rs 12 Crores only had been availed. This had been noted with concern

at higher levels. Out of more than Rs 9,000 Crores total sanctioned amount, about Rs. 600 crores

only had been utilized so far.

9.1.17 Director (G&TM), APTRANSCO that project schedule was of two years but they were expediting

to complete 1-2 months earlier. The tendering process needed to be followed, and since it included

both replacement and new procurement, tendering process was getting delayed. However, within

9-10 months from Zero date all material would be procured. Any nonperformance could only be

reviewed at the end of the project that is 2 years. The projects would be however completed within

the stipulated time period.

9.2 Assessment of lift irrigation loads and necessary planning for using as demand response

9.2.1 In the Sub Committee /Special Meetings, states had been suggested look into optimizing lift

irrigation/other pumping schemes existing in their system for Load Generation Management/RE

issues/load change over. Running these loads at different times could help in improved load

generation management.

9.2.2 In the Meetings, it had been noted that TS was considering utilization of the lift irrigation loads for

better RE integration.

9.2.3 States had been requested to kindly study this aspect and interact with Government

Bodies/irrigation department to utilize these schemes for improved flexing of the loads.

9.2.4 SRPC suggested constituents to kindly consider the possibility of using lift irrigation loads also as

part of demand response.

9.3 Operation of existing units in pump mode

9.3.1 A Special Meeting had been convened at SLDC, TSTRANSCO with participation from AP, TS,

SRLDC & SRPC Secretariat. Recommendations finalized w.r.t pump mode operations of

Nagarjunasagar are given below:

TSGENCO to address issues for filling up the Tail Pond Reservoir i.e. legal issues, elevating

the lift irrigation schemes etc. Also, TSGENCO to test pump mode operation through their

OEM M/s Hitachi.

Issue of discharges (quantum / time duration) / mechanism for enabling pump mode

operation/utilization of the water pumped back could be referred to CEA /MoP for further

guidance and suitable directions. This could help in utilization of Nagarjunasagar units in

pump mode in an optimal manner especially with higher renewable integration.


Following were the recommendation finalized w.r.t Srisailam pump mode operation:

Issue regarding weir could be taken up with CEA /MoP for further advice/guidance/funding.

Though it could take 2-3 years for completion but with high targets of renewables addition,

this would be useful in pump mode operation at Srisailam and balancing of RE.

Issue regarding discharges (quantum/time duration) / mechanism for enabling pump mode

operation/utilization of the water pumped back could be referred to CEA /MoP for further

guidance and suitable directions. This could help in utilization of Srisailam units in pump

mode in an optimal manner.

9.3.2 TCC deliberations

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

getting submerged and needed to be elevated. Shifting of the lift irrigation scheme (under

private sector) is under progress. OEM M/s Hitachi had visited in July 2017 and approved

operation of N‟Sagar units in pump mode. Once lift irrigation scheme gets elevated and with

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

With regard to Srisailam / N‟Sagar pump mode operation, TSGENCO was suggested to kindly

take up issues, requiring attention of CEA.

SRPC deliberations

9.3.3 CMD, TSTRANSCO & TSGENCO informed that the Tail Pond reservoir is ready and was to be

handed over to TS. Recently OEM, M/s Hitachi had inspected all the units and they had approved

the commissioning.

9.3.4 MD, APGENCO informed that the proposal for handing over of the dam has been submitted to

Government and was under consideration. The views expressed in SRPC Meeting would also be

communicated to Government to take the decision at the earliest. Being an interlinked issue with

Puluchintala, the handing over was awaiting formalization.

9.3.5 CMD, TSGENCO said that the Tail Pond was for pump mode and due to some administrative

reasons there had been some delay.

9.3.6 MS, SRPC stated that in the CEA Meeting, Member (Planning), CEA had suggested that issues

with regard to pump mode could be taken up with MoP/ Member (Hydro) by TSGENCO.

9.3.7 MD, APGENCO noted that Tail Pond dam was constructed with the intention of utilizing the

N‟sagar units in pump mode and also the Tail Pond units were constructed to utilize 50 MW

power..

9.3.8 Regarding Srisailam, CMD, TSGENCO said that 540 feet level was required to be maintained at

N‟sagar for pumping operations. The weir had been washed out and would have to be re-planned.

For weir construction they had already approached the concerned Central body. With good release

from Almatti, pump operation at Srisailam may be possible. If any issue is perceived, it would be

taken up with MoP/CEA.

9.4 Pump Storage Plants

9.4.1 A Meeting had been convened by CEA on 28th

June 2017 (MoM dated 17.07.2017 enclosed as

Annexure-XVIII) regarding utilization of existing pumps in the country. CEA had informed the


following about upcoming Pump Storage Plants in SR:

State PSP Scheme Status

Andhra Pradesh Upper Sileru (1000 MW) DPR being prepared

Tamil Nadu Kundah (500 MW) DPR prepared

5 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)

Issues in this regard, as also noted in the Hyderabad Meeting, had been taken up by SRPC with

Member (Hydro), CEA vide letter dated 06.07.2017 (Annexure-XIX).

SRPC deliberations

9.4.2 SRPC suggested the constituents to follow the pumping schemes with concerted efforts.

9.5 Power Flow Analysis under high RE scenario

9.5.1 SRLDC vide E-Mail dated 08.06.2017 had informed that a project had been undertaken jointly by

POSOCO, USAID and NREL for power flow analysis under high RE scenario. This study would

look into reliability and security issues with high RE penetration. As a part of Phase-I of this work,

studies are proposed to be conducted for 2018 grid scenario. For this purpose, States were kindly

requested to share details of existing wind & Solar generator details and Wind and Solar expected to

be commissioned by July 2018 with details of planned transmission system. It had also been

requested to kindly fill in details sought as per the attached format. A sample wind station diagram

was also attached for reference.

9.5.2 The following had been noted in the TCC Meeting:

TSTRANSCO, TANTRANSCO & KPTCL had already furnished the relevant information.

APTRANSCO informed that system study group had carried out Analysis with Spanish Consultant

around two weeks back and report was awaited.

SRLDC requested APTRANSCO & KSEBL to kindly furnish the information at the earliest.

9.5.3 SRPC noted the above.

9.6 Typical ramps of Solar

9.6.1 Typical ramps for the 250 MW NP Kunta solar plant are given in Table below:

Ramp

No.

Time

blocks

Approx. Time

(Hrs.)

Average

ramp (MW/

block)

Ram rate %

installed

capacity

Remarks

1 26 to 27 6:15 to 6:45 +5.5 2.2% Slow ramp up

2 28 to 38 6:46 to 9:30 +12.5 5.0% Steep ramp up

3 39 to 45 9:31 to 11:15 +6.1 2.4% Slow ramp up

4 46 to 53 11:16 to 13:15 2 to 3 1% to 1.5% Generation more or less


same

5 54 to 58 13:16 to 14:30 -5.4 -2.2% Slow ramp Down

6 59 to 69 14:31 to 17:15 -12.5 -5.0% Steep ramp Down

7 70 to 73 17:16 to 18:15 -6.3 -2.5% Slow ramp Down

9.6.2 These Ramps could be used for balancing/reserve planning by entities. The installed capacity could

be scaled suitably for this purpose. This exercise assumes significant importance in view of the fact

that Solar trajectory is quite high and would form large component of the RE / installed capacity of

the states. This would be an apt time to use such tools for better load generation, balancing / reserve

assessment / planning.

SRPC deliberations

9.6.3 Constituents were kindly requested to consider this aspect for better reserve planning, balancing etc.

10. COMPLIANCE OF CEA REGULATIONS FOR GRID CONNECTIVITY OF RENEWABLE

ENERGY SOURCES

10.1 CEA vide letter dated 12.04.2017 (Annexure-XX) had stated that in compliance of Clauses 6(3) and

6(4)(b) of CEA (Technical Standards for Connectivity to Grid) Regulations 2007 and CEA

(Technical Standards for Connectivity of the Distributed Generation Resources) Regulations 2013

notified on 30th

September 2013, it is obligatory for all grid connected renewable generators to

provide necessary facilities for data-communication and data-storage and other parameters as may be

stipulated. The said CEA Regulations also place onus on the generating plants including renewable,

to coordinate with appropriate licensees on issues including, but not limited to protection safety and

metering.

10.2 With the above perspective emerging from the CEA Regulations, SLDCs had been kindly requested

to take up the matter with all renewable generators to ensure transfer of data to the appropriate Load

Despatch Centre, so that real time generation data is available with them for centralized monitoring.

It was also requested to indicate present status in this regard and the action plan with definite time

frame to ensure real time data telemetry from the entire grid connected Renewable Generators/Plants

to SLDCs. CEA had requested SRPC to take up this issue with concerned SLDC/utility operating the

SLDC.

10.3 Subsequently, CEA vide letter dated 08.05.2017 (Annexure-XXI) had conveyed contents of MoP

letter dated 06.04.2017. The same are given below :

CEA to ensure that necessary rules and regulations regarding generation data communication

including RE generators are in place and being implemented in true spirit along with the

suitable monitoring mechanism/penal mechanism for non-compliance.

National level Registry to be maintained by Central Electricity Authority (CEA), where

generation capacity data of all kind of Generators (Conventional, Non-conventional, Non-captive,

Captive ISGS or ISGS) would be available. State level Registry shall be maintained at the

respective SLDCs also where generation capacity data of all kind of Generators (Conventional,

Non-conventional, Non-captive, Captive) in the respective States will be available. State level


data should further be communicated to CEA and NLDC for maintaining record at National level

on real time basis.

Data communication system for Discom embedded Renewable Energy generators (Solar, Wind,

Roof-Top Solar etc) is not available in a number of cases, because of which real time generation

data is not available. Availability of data communication system is very vital considering Grid

security aspects.

Further, to have availability of data of installed Capacity (including RE capacity) in the country,

it is desirable that a data Registry-at State as well as National level be put in place for

compilation of generation data of all kind of Generators (Conventional, Non-conventional, Non-

captive, Captive ISGS or ISGS).

It had been requested that in order to work out a necessary framework, inputs be collected from the

relevant stakeholders. It was requested to send to CEA the relevant inputs including suggestive

framework of rules, appropriate mechanism, penal provisions for non-compliance and a fool proof

mechanism of implementation of the framework.

10.4 SRPC vide letter dated 23.05.2017 had informed RES Division, CEA that during deliberations in

the Subcommittee Meetings, it was noted that data availability for roof top solar at SLDCs would

be rather difficult with available infrastructure at the DISCOM level and also it was dispersed. It

was requested that it may be clarified whether data/communication availability of all Roof Top

solar would be required at SLDCs.

10.5 The matter had also been deliberated in the Special TCC Meeting held on 20.05.2017 (refer

Annexure-XV). The updated status is given below:

State SCADA availability as on 30th

June-17

Mapped/IC

SCADA availability as informed

in CEA‟s meeting held on 28th

June 2017

Mapped/IC

AP Wind: 3563.071/3713.071 MW

Solar: 1800/1875 MW

Wind: 95.5%

Solar: 96%

TS Wind: 100.8/100.8 MW

Solar: 1230.5/1726.986 MW

All 23 RE generators connected at

& above 132 kV : 1044/1044 MW

RE generators connected at 33 kV

below : 323.24 (41 RE generators) /

756 MW (63 RE generators)

KA Wind: 3600.03/3600.03 MW

Solar: 1014.4/1014.4 MW

Wind: 3595.23/3595.23 MW

Solar: 1086.4/1086.4 MW

KE Wind: 16/59.275 MW

Solar: 36/71.036 MW

Wind: 22/65.475 MW

Solar: 36/71 MW

Hydro: 87.5/194 MW

TN Wind: 2500/7850 MW

Solar: 648/1850 MW

Wind: 2105 (92 WEGs) MW

10.6 CEA had conducted a Meeting on „Receipt of online operational data in real time mode at SLDC

from renewable energy generation sources (RES) and related issues‟ at New Delhi on 28.06.2017


(MoM dated 14.07.2017 enclosed as Annexure-XXII). The following was concluded in the

Meeting:

All states should have in place urgent time bound plan to ensure availability of 100 %

operational data in real time mode at the SLDC/RLDC/NLDC. It was decided that the

respective states would submit weekly reports of data communication status to CEA as well

as to respective RPC/RLDC and NLDC.

Till the time, State Regulations are not in place, CERC (Communication System for inter-State

transmission of electricity) Regulations, 2017 shall be followed.

10.7 A Special Meeting was also conducted in CEA on 11.07.2017 under Chairmanship of Member

(Planning), to discuss modalities for devising suitable framework for National Level Data

Registry for electricity generating units so as to have easy availability of their generating capacity

and other details. CEA vide letter dated 19.07.2017 (Annexure-XXIII) had communicated the

Minutes of the Meeting.

10.8 The following had been noted in the TCC Meeting:

All constituents were requested to kindly furnish weekly report of data communication status

to CEA / SRPC / SRLDC / NLDC. 100 % data availability of RE in real time was to be

ensured and there needs to be a time bound plan in place.

SRLDC had stated that since REMCs were coming up, the same data would be required.

Therefore, concerted efforts in ensuring RE data to SLDC/RLDC/REMC were required.

Constituents had expressed concern regarding real time data from Roof Top Solar with the

present level of infrastructure.

SRPC deliberations

10.9 MS, SRPC pointed out that real time data availability of grid connected RE to SLDC was to be

ensured as per CEA Regulations and was a critical issue being monitored at highest level. He

requested the states to focus and prioritize it. There was also a move on initiating National/State

Level Data Registry of Generating units and CEA was preparing the formats etc in this regard.


11. TERMS OF REFERENCE FOR RENEWABLE INTEGRATION – TASK FORCE

11.1 In the 30th

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

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

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

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

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

the TOR was finalized. It was further felt prudent to fine tune the TOR in discussion with

experts/staff of POSOCO etc., to avoid any possible duplication in the proposed study.


As per preliminary assessment, the cost could be around Rs.3.50 crores.

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


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

grid.

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

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

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

11.4 SRPC Secretariat had discussed TOR with experts/staff of CERC & POSOCO and had

communicated the same to TANTRANSCO vide letter dated 03.05.2017 (Annexure-XXIV) for

further necessary action.

11.5 Subsequently TANTRANSCO vide letter dated 08.06.2017 (Annexure-XXV) had informed that the

matter regarding possible funding of the consultancy had been taken up with RE Developer

Association on 30.05.2017. After deliberations, the following had been suggested by the RE

developers:

Objective of the study on RE integration is highly elaborative which gives solution on long term

that is up to year 2030. Hence, the study should be based on short term (immediate), Medium

term (for year 2022) and long term (for year 2030).

As per preliminary assessment of SRPC, the cost could be around Rs.3.50 crores. In this regard,

the amount may be segregated separately for short term (immediate), Medium term (2022) and

long term (for year 2030) so that the cost may come down.

Also, the study may be carried out in separate heads as Technical, Commercial and Training &

Administration. Hence, instead of a single consultant, one may engage more than one consultant

for different heads of study.

It was requested to conduct Meetings with all the other RE rich states in SR/India with their RE

developers association (including solar) so as to share the financial commitment equally.

It was agreed in-principle by IWPA during the meeting to share the cost, if the cost is cut down

from 3.5 Crore (preferably in lakhs) after taking the above suggested measures.

11.6 The way forward in this matter was kindly requested to be identified.


It appeared that states may need to fund this study or else the study could be dropped.

A separate Meeting would be conducted at SRPC with participation from Constituents‟ / RE

Developers. TANTRANSCO consented to coordinate participation of RE Developers.


12. UPCOMING TRANSMISSION SYSTEM

12.1 Upcoming inter-regional transmission schemes

12.1.1 KSEBL vide letter dated 14.08.2017 (Annexure-XXVI) had requested for review of schemes

associated with system strengthening beyond Vemagiri and 765 kV Warora (Pool) - Warangal

(New) D/C line.


12.1.2 Updated status is furnished below please:

S S.No. Transmission Element Remarks

a) 765 kV Wardha – Nizamabad-

Hyderabad D/C line

Original Schedule by May 2018.

765 kV Wardha-Nizamabad D/C line commissioned on 24.04.2017

Dichipally – Dichipally (HTLS)D/C line commissioned on 24.04.2017

765 kV Nizamabad-Maheshwaram (Hyderabad) D/C section charged

on 22nd

July 2017 and declared on COD from 27th

July 2017.

1 No of 240 MVAR switchable line reactor each at Nizamabad and

Maheswaram for the above line declared on COD from 27th

July 2017.

1500 MVA Transformer-I at 765/400 kV Maheswaram (Hyderabad)

declared on COD from 27th

July 2017.

2 Nos 240 MVAR Bus reactors at Maheswaram declared on COD

from 27th

July 2017.

400 kV Maheswaram – Kurnool S/C line declared on COD from 27th

July 2017.

M/s Sterlite scope: N‟zamabad-Shankarpally & Maheswaram –

Mehaboobnagar - Expected by end of August 2017.

PGCIL placed on record the active support extended by TSTRANSCO

in resolving the ROW issues.

31st TCC :

CTU informed that there could be increase in TTC in a progressive manner

with the commissioning of the elements.

b) WR-SR 6000 MW HVDC Bipole Link

[Raigarh (Chhatisgarh) - Pugalur-

Trichur (TN/KER)]

Apr‟ 2020

31st TCC:

PGCIL informed that the works at both the terminals had commenced. The

line works from Raigarh to Pugalur had started in all the regions (WR-I, SR-I

& SR-II). Top management was putting all efforts to complete the works by

December 2019. Efforts are also being made to advance it.

c) 765 kV Angul - Srikakulam PS D/C

Corridor

Main corridor commissioned. Other

associated elements by July 2018.

31st TCC :

PGCIL informed that Garividi- Srikakulam PS was expected by March 2018.

APTRANSCO informed that the downstream system would also match.

TSTRANSCO expressed concern that there was not much increase in TTC with

the commissioning of Angul-Srikakulam.

CTU informed that the TTC assessment could be carried out in the sub group

study. Major increase would be after the commissioning of system

strengthening lines beyond Vemagiri.


d) Additional inter-Regional AC link for

import to Southern Region, i.e.,

Warora - Warangal - Hyderabad-

Kurnool 765 kV link

TBCB, PFCCL- BPC Schedule was 40 months from the

transfer of SPV on 06.07.2016

(around Nov 2019).

Discussed in 36th

Meeting of

Empowered Committee scheduled

for 26.07.16

Hon‟ble CERC in its Order dated

29.09.2016 in respect of Petition

No 111/TL/2016 had granted

Transmission License to Warora-

Kurnool Transmission Limited

(WKTL).

e) System strengthening within SR for

transmitting power beyond Vemagiri

TBCB- RECTPCL-BPC–Some

scope of work/ reactive

compensation modified.

The project has been awarded to

PGCIL under TBCB, and was

expected by April 2019.

31st TCC:

PGCIL informed that 765 kV Vemagiri – Chilkaluripeta – Cuddapah D/C and

400 kV Cuddapah – Madhugiri D/C expected by Q1 of 2018-19.

Removal of constraints in Vemagiri area was expected to be completed by

October 2017. APTRANSCO expressed concern over the line loading issues in

Vemagiri area.


12.1.4 Updated detailed status of upcoming inter regional scheme is furnished at Annexure-XXVII.

12.2 Pending transmission elements in WR and SR for proper utilization of 765 kV Raichur-

Sholapur line (Out of planned 18 elements)

12.2.1 Updated status of pending transmission elements in WR and SR for proper utilization of 765 kV

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

Sl.

No

Name of

Transmission

Element

Exe.

Agency

Sch. CoD Expected

date

Remarks

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

Raichur- Sholapur line (Out of planned 18 elements)

1 400 kV Tumkur-

Yelahanka D/C

line

PGCIL June 2014 31st TCC :

Sep 2018

Severe RoW

problem. 400 kV

Yelahanka S/S is

ready.

30th

TCC: SR-II informed that in the recent Meeting held on 18.02.2017 with

Secretary, Power and Chief Secretary, GoK, police protection was assured to carry

out the works.

2 400 kV

Nelamangala-

Hoody LILO at

PGCIL 31st TCC :

Oct 2017


12.2.2 PGCIL had filed Petition No. 114/MP/2014 in the matter of „Petition under Section 79 (1) (c) of

the Electricity Act, 2003 read with Regulation 54 “Power to Relax” and Regulation 55 “Power

to Remove Difficulty” of the CERC (Terms and Conditions of Tariff) Regulations, 2014 and

Regulation 24 read with Regulation 111 of the CERC (Conduct of Business) Regulations, 1999

and Section 67 (4) of the Electricity Act, 2003 to adjudicate the difference or dispute arisen with

regard to the compensation, as detailed in the petition and seeking direction from this Hon‟ble

Commission relating to construction of 400/220 kV Yelahanka sub-station and LILO of

Nelamangala-Hoody 400 kV S/C (Quad) line at 400/220 kV Yelahanka sub-station under System

Strengthening in Southern Region-XIII and construction of Madhugiri Yelahanka 400 kV

D/C(Quad) line under System Strengthening in Southern Region XIII.‟ In the Order dated

18.04.2017, the Commission had stated „…………As per the High Court order, the State

Government is bound to provide necessary right of way to the Petitioner to complete its project.

Since, the High Court has already directed the State Government to provide necessary

assistance to execute the project, the order of the Hon`ble High Court holds the field and has to

be implemented by the State Government. If the Petitioner is aggrieved, it has the remedy to

again approach the High Court for ensuring compliance of the directions of the Hon`ble High

Court by the State Government. ……The Petitioner is directed to take steps for completion of

transmission line at the earliest.‟

SRPC deliberations

12.2.3 MD, KPTCL informed that cable had arrived and works at Yelahanka were scheduled to be

completed by December 2017. It passes through newly constructed State Highway and PWD was

charging some hefty sum but the issue has been resolved. Tumkur- Anthrasanahalli would be

completed by month end while other line would be completed by December 2017.

kV Yelahanka

3 220 kV Tumkur –

Antharasana Halli

D/C

KPTCL Tenders for

the above line

had been

placed on

18.03.15 and

it would take

18 months for

completion

31st TCC :

Completed

4 220 kV Tumkur

(400 kV) S/S –

220 kV Tumkur

S/S D/C

KPTCL 31st TCC :

Sep 2017

31st TCC :

All towers completed

and stringing of 4

kms to be carried out.

5 220 kV

Yelahanka

(400/220 kV)

S/S- 220 kV

Yelahanka S/S

D/C Cable

KPTCL (5.875 kM) 31st TCC :

December

2017

31st TCC :

Cable had been

received, ROW issues

being resolved.


12.3 Status of various Transmission Systems

12.3.1 KSEBL vide letter dated 14.08.2017 (refer Annexure-XXVI) had also requested for review of 400

kV Somanahalli – Dharmapuri (Salem New) D/C line.

12.3.2 Updated status of associated links is furnished below please:

Transmission

Elements

Line

Lengt

h

(ckm)

Impleme

nting

Agency

Sch

COD

Ant

COD/

Act

COD

Constraints/

Remarks

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

Power Ltd, Tuticorin Area

765 kV S/C Salem PS

(Dharmapuri) -

Madhugiri P S line

(initially charged at

400 kV)

243.23 PGCIL Dec'14 31st

TCC:

Nov

2017

Severe ROW

problems in

Karnataka. Critical.

Covered under

PRAGATI.

Transmission system associated with IPPs of Nagapattinam/Cuddalore Area–

Package A

Salem New –

Madhugiri 765 kV S/C

line.

219 (PNMTC

L) (A

subsidiar

y of

PGCIL)

Mar‟

15

March

2018

Severe RoW issues

being faced in

Karnataka.

Transmission System Associated with Contingency plan for Evacuation of Power

from IL&FS ( 2 x 600 MW)

Stringing/ upgradation was pending within NLC Complex. PGCIL has planned it during

October 2017.

Transmission evacuation system for HNPCL (1,040 MW) Power Plant

400 kV TM D/C

HNPCL -

Kamavarapukota

200

(Lot-I,

II &

III)

APTRA

NSCO

Jul

„15

31st TCC:

Commiss

ioned

400 kV TM D/C

Kamavarapukota -

Vemagiri

185 APTRA

NSCO

31st TCC:

Alternate options being explored,

would be taken up with the

Standing Committee.

400 kV TM D/C

Kamavarapukota -

Chinna Korukondi

179 APTRA

NSCO

Sept.

„15

31st TCC:

Commiss

ioned

Kamavarapukota

Substation

2x315

APTRA

NSCO

Mar

„16 Commissioned on

S/S : 25.01.2017

ICT-1 : 20.02.2017

ICT-2 : 17.03.2017

Suryapet Substation 2x315

TSTRAN

SCO

ICT-II by

July 2017

ICT-1 charged on

17.03.2017

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

MW in Phase-I) of NTPC Limited


400 kV Kudgi TPS –

Kudgi (PG) 2nd

D/C

Line

M/s KTL

(L&T

IDPL)

Feb-15 Completed Trial Run

on 25.02.2017

220 kV D/C line to

Vajramatti

KPTCL Awarde

d – 1

year

ROW issues

220 kV D/C line to

Basavana Bagewadi

KPTCL 30th

TCC :

50% complete

220 kV D/C line to

Bijapur

KPTCL 30th

TCC :

50% complete

Transmission System for evacuation of power from Singareni Collieries

Generating Project (2 x 600 MW)

STPP, Jaipur –

Jagityal

139 TSTRAN

SCO

31st

TCC:

Nov 17

Works Awarded on

Nov‟15.

Jagityal - Nirmal 148 TSTRAN

SCO

Feb 17 Ready 31st TCC : Nirmal

SS by Nov 2017

Transmission system of KPTCL for evacuation of power from Yermarus TPS ( 2 x

800 MW)

Bellary 400 kV PS

near „BTPS‟

Compl

eted

31st TCC :

Deployed manpower

Gulbarga 400/220 kV

substation

2x500

Land acquired. Geo

tech survey work to

be awarded within a

week. BoM prepared

and estimate to be

prepared.

Yermarus TPS -

Gulbarga 400 kV D/C

line (QM)

Detailed survey

completed. Estimate

is being prepared.

400 kV SS at

Chikkanayakanahalli

(C.N Halli) near LILO

point on the

Nelamangala –

Talaguppa 400 kV

lines to Hassan.

2 x 500

MVA

Step-down

SS agreed

in 39th

SCPSPSR

30

th TCC:

Land yet to be

identified. Alternate

site at Bindikere is

under consideration

Land acquisition is

under progress.

LILO of Nelamangala

– Talaguppa 400 kV

D/C at CN Halli.

Linked with CN

Hally station

Land acquisition is

under progress

Termination of 400

kV D/C of Hassan

from Nelamangala –

Talaguppa at CN Halli

400

After CN Halli land

identification, survey

would be taken up.

Yermarus TPS -

Bellary PS 400 kV

D/C QM

(400 kV MC (5.138

285

Expecte

d by

Aug‟17

213 ckm out of 285

completed


Kms) and 400 kV D/C

line(137.355 Km) =

142.493 Kms)

Bellary PS -

C.N.Hally 400 kV

D/C line QM

360

29

th TCC update:

Part of the work from

Rampura-Jagalur 65

kM had been

awarded.

Bellary PS to

Madhugiri (PGCIL)

a) Madhugiri to

Rampura limits):

400 kV D/C QM

Bellary PS to

Rampura limits

(KelaginaKanavi)

188.74

43.018

364

86

22-12-

16

24-04-

17

Comple

ted

Comple

ted

31st TCC :

Testing under

progress. Would be

commissioned

shortly.

Bellary TPS – Bellary

PS 400 kV D/C QM

10

Dropped in 39th

SCPSPSR

De-link 400 kV S/C

RTPS-BTPS-JSW-

Guttur with JSW Bus

Nov‟16 Agreed in 39

th

SCPSPSR

Once 400 kV M/C

line from JSW to

BPS the link between

JSW & BPS will be

delinked.

JSW TPS – BPS

Station 400 kV D/C

line QM

Comple

ted

Additional JSW TPS –

BPS 400 kV D/C

(QM)

Agreed in 39

th

SCPSPSR

400 kV BTPS-Guttur

D/C (QM)

Agreed in 39th

SCPSPSR

Transmission System for Rayalaseema TPS (600 MW)

RTPP - Pedda

Jamgam Palli -

Chittoor

216+

212

APTRA

NSCO

Test

charge

on

22.05.2

017

400/220 kV, Kalikiri

S/S

2 x

315

MVA

APTRA

NSCO

Sep‟17 30th

TCC:

2018-

19

PO is placed in Nov-

15.Site handed over

on 23.06.2016

LILO of Rayalseema

IV-Chittoor 400 kV

D/C at Kalikiri

81

APTRA

NSCO

Status of upcoming links having impact on S1-S2

400 kV Somanahalli-

Dharmapuri PS

243 PGCIL Jun‟15 31st

TCC:

Decem

Severe RoW

problems being faced

in Karnataka.


ber

2017

Compensation issues

under progress.

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

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

line corridor. With this, cost of 30 kM line was working out to as high as Rs 90 crore. It

would take around two months to complete the work once ROW issues are resolved.

400 kV Mangalore

(UPCL ) -Kasargode-

Kozhikode

TBCB In the 39th

SCPSPSR, it was noted that the

process of implementation in TBCB or

regulated tariff in compressed time

schedule will be initiated as applicable.

KSEBL vide letter dated 14.08.2017 (refer Annexure-XXVI) had observed 400 kV

Udupi – Kasargode D/C line is very much essential and critical for maintaining power

stability in the region and for reaping expected benefits of planned links under

TransGrid 2.0 scheme sanctioned for the state for meeting expected demand growth in

Northern part of Kerala and for supporting energy security. It is imperative that

construction of the line needs to be completed on war footing basis. However, it is yet to

be taken up for investment approval and further related activities. It has been requested

that the matter be discussed and taken up with GoI for further necessary action.

31st TCC :

KSEBL had expressed concern and stated that the line needs to be expedited.

NPC had informed that earlier the line was UPCL – Kasargode and Kasargode –

Kozhikode. Both were to be built under TBCB. Later in the Standing Committee, it

had been agreed that Kasargode – Kozhikode would be taken up by KSEBL.

Subsequently KSEBL had suggested for LILO of Mysore – Kozhikode in Wynad

(Switching station) and Wynad would be linked with Kasargode. Present

configuration needed to be studied.

KSEBL had stated that link from UPCL would provide anchoring since at present

they were fully dependant only on Mysore link. There was not much change as load

centers were Kasargode and Kozhikode. It will also be helpful after the

commissioning of the HVDC link to Madakathara since there would be a ring which

would help improve reliability. It would help in voltage improvement also.

CTU had stated that earlier KPTCL and UPCL were having certain reservations and

KPTCL could participate in the study at CEA. UPCL was also planning 2 x 800 MW

expansions and hence the scenario was to be studied in totality.

It was suggested that a Meeting in this regard be conducted on 28.08.2017 at CEA

before the Standing Committee / Empowered Committee with participation from

KSEBL, KPTCL, CTU and CEA.

32nd

SRPC:

CMD, KSEBL stated that he was happy that decision for early study in CEA had been

taken. This line was extremely critical for them to implement the project called

TransGrid, since this project envisages uprating of existing lines using the same

ROW. Disruptions would be tremendous in north Kerala during the uprating works.

If this line comes the existing lines can be uprated without much interruption. This

aspect was quite significant for the state. It has already been cleared by Standing

Committee and need not be taken to that Committee once again.

SRPC noted the above.

Critical Intra-regional transmission elements


400 kV Edamon-

Kochi

286 PGCIL

31st

TCC :

Sept

2018

Being monitored

under PRAGATI.

31st TCC: Line work

progressing

SRPC/TCC deliberations:

KSEBL had confirmed that the compensation disbursement was planned from 1st

March 2017 onwards and ROW of around 10 kms in phases would be handed over to

PGCIL to take up the works. With disbursement, the resistance was likely to come

down. From 1st April 2017, PGCIL was likely to commence works.

SR-II, PGCIL had informed that a new contract would be awarded by March 2017

with likely schedule of 18 months. Works would commence once compensation

issues are settled.

PGCIL had filed Petition No. 83/MP/2014 in the matter of „Petition under Section

79 (1) (c) of the Electricity Act, 2003 read with Regulation 54 “Power to Relax” and

Regulation 55 “Power to Remove Difficulty” of the Central Electricity Regulatory

Commission (Terms and Conditions of tariff) Regulations, 2014 and Regulation 24

read with Regulation 111 of Central Electricity Regulatory Commission (Conduct of

Business) Regulations, 1999 and Section 67 (4) of the Electricity Act, 2003 to

adjudicate the difference or dispute arisen with regard to the compensation, as

detailed in the petition seeking direction from the Commission relating to

construction of Edamon-Muvattapuzha (Cochin) 400 kV D/C line section of

Thirunelveli- Muvattapuzha (Cochin) 400 kV D/C (Quad) transmission line‟. In the

Order dated 18.04.2017 the Commission had stated „……It was argued during the

hearing that the other States may follow the example of Kerala and fix high

compensation rates and indulgence of the Commission was sought for the issue of

direction in this regard. In our view, this Commission cannot prescribe any rate for

compensation for the line corridor and line facility. It is however noted that the

Ministry of Power, Government of India has issued guidelines to the State

Government and Administrators of UTs with regard to the amount of compensation

payable for right of way for transmission lines. The same may be kept in view by the

Petitioner while paying the compensation. The dispute regarding the compensation

between the petitioner and the Govt. of Kerala having been decided by the Hon`ble

High Court is not maintainable before this Commission………..The Petitioner is

directed to take steps for completion of transmission line at the earliest.‟

12.4 Associated Transmission Evacuation Schemes in Tamil Nadu

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

SCPSPSR, which

were modified in the following Standing Committee Meetings, is given below:

Generating Station Likely COD Evacuation Status

Ennore TPS Expansion – 1 x

660 MW

2019-20

Ennore SEZ (NCTPS Stage-IV)

– 2 x 660 MW

2018-19

NCTPS Stage III – 1 x 800 MW 2019-20

Ennore TPS Replacement – 1 x 2019-20


660 MW

765/400 kV, 2 x 1500 MVA

Ariyalur SS

31.3.2019 Work awarded to M/s BHEL

on 31.03.2017.

765/400 kV, 3 x 1500 MVA

North Chennai PS (GIS)

2019-20 Price bid opened on

02.06.2017 and under

evaluation.

765/400 kV, 2 x 1500 MVA

Coimbatore SS

2020-21 Administrative approval

accorded. Alternate land is to

be identified.

765 kV Ariyalur – Thiruvalam

(PG)

07.04.2018 Work awarded to M/s

Gammon India. Works under

progress.

765 kV North Chennai PS -

Ariyalur

2019-20 Tenders opened on 16.06.2017

and under process.

400 kV Ennore SEZ-North

Chennai PS

Tender opened on 07.06.2017

and under evaluation. BLTC

note for price bid opening is

sent to Account for remarks. 400 kV Ennore SEZ- Ennore to

ETPS Expn

400 kV ETPS Expn – North

Chennai PS

Interconnection from common

point of SEZ – ETPS Expn to

NCTPS Stage-II and LILO of

NCTPS-II – SV Chatram 400

kV MC between location No.21

& 22

12.5 Commissioning Schedule of Downstream system of Discoms

POWERGRID vide letter dated 4th

August 2017 (Ref Annexure-XI) had intimated that the

following assets are under implementation. However, implementation of downstream 220 kV

system needed to be expedited for effective utilization of the system.

a) 2 x 500 MVA transformers at Madhugiri Sub-station.

b) Kanchipuram SS of TNEB for termination of Kalpakkam PFBR – Kanchipuram line.

TANTRANSCO informed that the Kanchipuram S/S would come up by December 2017.

c) Trichy 1 x 500 MVA 400/230 kV ICT.

12.6 Status of Various upcoming Lines

12.6.1 POWERGRID vide letter dated 4th

August 2017 (Ref Annexure-XI) had intimated status of

commissioning of various elements in the Southern Region.


It was noted that there were various issues such as elements linked with RE generation,

corresponding downstream availability, part element commissioning affecting ATC etc which

required further study.

PGCIL had informed that they would be proceeding with the projects which are in a good

tenor of completion such as Maheswaram bay extension by August 2017, removal of

constraints in Vemagiri by October 2017, NP Kunta (SS 24 - 4th

transformer, NP Kunta-

Hindupur, LILO of Kurnool-Thiruvalam at Cuddapah) by end of December 2017 or in Q4.

It was agreed that a separate Study Group (including participation from CTU) would meet

within 10 days to assess likely advantages / benefits for grid operation/system reliability with


the commissioning / early commissioning of these elements.

Report of this Study Group would be submitted to Chairperson, SRPC for necessary approval.

All the entities concurred to abide by the Report of this study group.

SRPC deliberations

12.6.3 CMD, TSTRANSCO placed on record the efforts put in by PGCIL for completing the Wardha-

Nizamabad - Dichipally corridor ahead of time. As a result TS got additional power from

Chattisgarh and TS was able to meet a peak demand of 9,460 MW during July 2017.

12.6.4 ED, SR-I, PGCIL stated that as can be appreciated there were severe ROW issues. There had been

regular structured meetings and with active support of Telangana Govt & CMD, they had been

able to complete the project. PGCIL would be going ahead for removal of constraint in Vemagiri-

the material from China had got delayed and now that all material had arrived, only

commissioning activities were pending. PGCIL had committed itself financially for all schemes

under SS-24 (NTPC had committed of additional generation in NP Kunta) and these elements

were nearing completion. Addressing ROW issues was a rather difficult process, building a line

was a herculean task and hence PGCIL should be allowed to go ahead with the commissioning of

the lines. Raigarh - Pugalur project had been launched and Management had given the mandate to

expedite it as early as possible. With the support of State Governments it would be made through.

Many of the projects had been commissioned ahead of schedule with the active cooperation of

states. As a result, the power supply position in SR had improved perceptibly.

12.6.5 Chief Engineer, NPC noted that ISTS is being constructed both by PGCIL as well as by

Independent Transmission Companies under TBCB. In instances where transmission projects are

being advanced, it would only be appropriate for studies to be carried out. The usefulness or not

of advancing needed to be studied by the utilities.

12.6.6 Chairperson, SRPC opined that in case it is advantageous to all stakeholders, the same can be

agreed.

12.6.7 MD, KPTCL stated that all line works and progress are subject to audit. In case upstream line is

completed before time with downstream system not being ready, there could be some audit issues.

A rational decision after due studies would thus be a better option. Notice regarding any early

commissioning of transmission assets should also be given to beneficiaries as a practice. This

would help in expediting and matching downstream completion in the same timeframe.

12.6.8 CMD, KSEBL stated that they also agreed for a Study Committee Meeting to take a final call.

12.6.9 It was thus agreed that usefulness of the early commissioning of the transmission elements would

be studied by the Study Group with participation from all constituent states, CTU, SRLDC &

SRPC Secretariat. SRPC agreed that this Study Group Study Group Report would be approved

by Chairperson, SRPC. Based on this, approval would be communicated to CTU by SRPC


Secretariat.

12.6.10 On a query about progress of Warora - Warangal – Hyderabad - Kurnool, ED, SR-I, PGCIL

informed that the line was under TBCB but bay extension at Warangal, Hyderabad & Kurnool

had already been started.

12.7 Operational Feedback

12.7.1 NLDC vide letter dated 21st July 2017 (available in NLDC website) had highlighted following

transmission constraints as part of Operational Feedback for the quarter April – June 2017 in

respect of SR:

Transmission Line constraints:

400 kV Nellore Pooling Station -Nellore D/C line

400 kV Gooty-Nelamangala line & 400 kV Gooty- Somanahalli line. Loading on these lines

have been partially relieved after 400 kV Tumkur-Bidadi-Nelam8angala rearrangement.

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 400 kV Vemagiri - Gazuwaka 220 kV Bangalore Metro Network

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

220 kV Sharavathy-Shimoga lines (3 nos) and 220 kV Sharavathy-Talaguppa (3 nos)

Constraints for Rayalaseema TPS Generation Evacuation – 30th

TCC: it was noted that the

constraints has been removed which had been confirmed by SRLDC. Constraints in Nagjheri PH evacuation Constraints in Chennai 230 kV System

Overloaded 230 kV Lines in Tamil Nadu

Constraints in 230 kV evacuation lines of MTPS and Kundah complex

Constraints in wind evacuation

ICT Constraints

400/220 kV 2 x 315 MVA ICTs at Gazuwaka –31st SRPC: It was noted that the requirement

needs to be ratified in the Standing Committee. SRPC approved in principle for 2x500 MVA

ICTs in place of existing ICTs. PGCIL was suggested to take up the issue in the Standing

Committee for ratification.

31st TCC: APTRANSCO had stated that replacement may not be possible as the ICTs are

already overloaded and suggested additional 500 MVA ICT. SR-I stated that they had

assessed the space requirement and additional ICT may be possible. CTU had stated that

they would take up the additional requirement of 500 MVA ICT in the Standing Committee

for ratification.

32nd

SRPC

CMD, APTRANSCO stated that a number of issues had been faced by APTRANSCO &

PGCIL in that area. He thanked ED, SR-I for kindly accepting for the third ICT.

SRPC agreed in Principle for additional 500 MVA ICT and that the matter would be

referred to Standing Committee by CTU for vetting.

400/220 kV 2 x 315 MVA ICTs at Vemagiri

31st TCC: SRLDC informed that even after commissioning of new ICT, the constraints

persisted.


32nd

SRPC: CMD, APTRANSCO informed that problem had reduced but once the Mardam

(Vijianagram) lines come up within two months, the issue would get addressed.

400/220 kV 3 x 500 MVA ICTs at Nelamangala

400/220 kV 3 x 500 MVA ICTs at Somanahalli

400/220 kV 3 x 500 MVA ICTs at Hoody

400/220 kV 2 x 315 MVA ICTs at Guttur

400/220 kV 2 x 315 MVA ICTs at Hiriyur

400/220 kV 2 x 315 MVA ICTs at Narendra

400/230 kV 2 x 315 MVA ICTs at Trichy

31st TCC: SRLDC informed that the constraint has been relieved.

400/230 kV 2 x 315MVA ICTs at Madurai

400/230 kV 2 x 315MVA ICTs at Thiruvalam

400/220 kV 2 x 315MVA ICTs at Kalpakka

400/220 kV 2 x 315MVA ICTs at UPCL

400/220 kV 3 x 315MVA ICTs at Shankarapally

TCC had suggested that the respective entities kindly identify and implement suitable short term and

long term measures to overcome these constraints in a time bound manner.

12.7.2 The following issues had been raised in OCC Meetings:

500 MVA additional ICT at Checkanoorani (Madurai) 400/230 kV S/s in PGCIL end was

commissioned on 29.12.2017. LV side 230 kV Bay work under scope of TANTRANSCO

was under progress and would be completed on 30.09.2017. TANTRANSCO had informed

that tender was opened on 16.05.2017

500 MVA additional ICT at 400 kV Alundur (Trichy) was commissioned on 10.06.2017. At

Alundur 230 kV substation Bay shifting works civil works (Plinth, Structure works) under

scope of TANTRANSCO were under progress and yet to be commissioned.

31st TCC: TANTRANSCO informed that the downstream system had been commissioned.

Completion of Kamuthi bays (2 nos) at Karaikudi

31st TCC

SRLDC letter dated 19.08.2017 (Annexure-XXVIII) had pointed out the high voltage

issues in TN stations and N-1 evacuation issues at Kamuthi.

PGCIL had informed the works may get completed by November 2017.

32nd

SRPC

ED, SR-II informed that there was some delay on part of TANTRANSCO in release of

funds etc but they are proceeding and would complete it by November 2017.

NLC ICTs

31st TCC

TANTRANSCO had expressed concern over loading conditions of NLC ICTs and

suggested for additional ICT.

NLC had stated that there was no space for additional ICT and the constraints may get

addressed after commissioning of NNTPS S/S. TANTRANSCO had also requested for

space for 400 kV S/S and NLC had replied that there were some space constraints. NLC

and TN had been requested to have a bilateral dialogue on the matter.

NLC/TANTRANSCO had been suggested to take up the upgradation issue in the ensuing

Meeting of Standing Committee on Power System Planning.


12.8 Issues related to implementation of LTA based transmission systems and Relinquishment of

LTA

12.8.1 TANGEDCO vide letter dated 16.08.2017 (Annexure-XXIX) had stated that in many cases,

POWERGRID started implementation of associated transmission system without confirming

firm up of source sink. Some of the IPPs/LTOA customers are unable to firm up their

generation/target beneficiaries due to various reasons and unable to enter into PPA. Thus, the

transmission schemes are completed without the scope for beneficial use, thereby creating

redundant capacity. Ultimately, the responsibility of paying the transmission charges is shifted

on the existing DICs in respect of schemes which are exclusively designed and executed for the

IPPs. It has been suggested that requirement for stringent measures to be taken for preventing

casting of responsibility and creation of redundant assets be discussed. Further, transmission

charges shall have to be recovered from the defaulting LTA customer in case of backing

out/relinquishment of LTA.


TANGEDCO had stated that there was no doubt what so ever that PGCIL was doing a

herculean task in completing various projects and enhancing connectivity throughout the

country. “Power for All” vision of Central Government cannot become reality without this

contribution of PGCIL. However, progress of generation and target beneficiaries‟

downstream system also needed to be periodically reviewed while planning / executing the

project. At times, projects were completed without much beneficial use and in case the

generators backed out the financial burden get passed on to existing beneficiaries. It was

suggested that stringent measures need to be taken against defaulters. Transmission charges

should be recovered from them and not get passed on to existing beneficiaries.

CTU had stated that there was a provision for relinquishment of LTA in Regulations. There

were provisions of Construction Bank Guarantee, application, signing of Agreements etc.

Only after satisfying all the requisite provisions, PGCIL takes up construction works.

Petition No 92/MP was still pending before Hon‟ble CERC and finalization of

relinquishment charges was still to be firmed up. TN was suggested to implead itself in this

petition. Construction Bank Guarantee (Rs 5 lakh/MW) as per Regulations was quite meager

in a way. Generators which had come up and were transacting under STOA / MTOA pay

applicable transmission charges and thereby DICs get compensated to that extent. Issue was

therefore more with regard to generators who had abandoned the project or were uncertain

and not with generators with commissioned units.

NPC had suggested that other DICs may approach Hon‟ble CERC at the earliest since the

matter regarding Relinquishment Charges may be finalized shortly.


13. UPCOMING RENEWABLE PROJECTS AND THEIR INTEGRATION WITH

TRANSMISSION NETWORK

13.1 Status update of upcoming evacuation schemes in Southern Region for renewable as given below is

furnished at Annexure-XXX.


S.No. State Project Type of Renewable

Project

Capacity in MW

1 TS Gattu Solar Park Solar 500

2 AP N.P. Kunta Solar Park Project Solar 1500 3 AP Ghani/ Panyam Solar Project Solar 1000

4 AP Aspiri Wind Project Wind 1000

5 AP Suzlon Power Project Wind 300 6 AP Various, at Uravakonda area Wind 1361

7 AP Various, at Kondapuram area Wind 1109 8 AP Various, at Hindupur area Wind 680

9 AP Mailavaram dist., Kadapa Solar 1000 10 AP Talaricheruvu dist., Ananthpur Solar 500 11 KA Tumkur(Pavagada) Ultra Mega Solar

Park Solar 2000

12 KA Gadag Wind Project Wind 80 13 KA Dhoni Wind Project Wind 587 14 KA Harti Wind Project Wind 244 15 KA Gadag Wind Project Wind 90 16 KA Gadag Wind Project Wind 197 17 KA Jagalur Wind Project Wind 177 18 KA Thalak Wind Project Wind 250 19 KA Thalak Solar Project Solar 200 20 KA Guttur Wind Project Wind 518 21 KA Davanagere and Chitradurga Wind 60 22 KA Davanagere and Chitradurga connected Wind

(proposed) 406

23 KA Athani Wind Wind 240 24 KA Chikkodi Wind 92 25 KA Chikkodi, Ghatprabha, Belgaum Wind 110

26 KA Chikkodi, Ghatprabha, Belgaum Wind 418 27 KA Atria Hydel Hydel 12 28 KA Cauvery Hydro Hydro 3

29 KA Pioneer Power Hydro 24.75 30 KA Pioneer Power Hydro 24.75 31 TN Mytrah Energy (India) Wind 300

32 TN Samimeru Wind farms Wind 48.5

33 TN SISL Green Infra Wind 48.5

34 TN Samiran Udaipur Wind farms Wind 48.5 35 TN Shivam Filaments Wind 48.5 36 TN R.S. India Global Energy Wind 480 37 TN Suzlon Power Infrastructure Wind 1000 38 TN Suzlon Power Infrastructure Wind 350 39 TN Vestas Wind Technology India Wind 150 40 TN Wind Projects at Samugarengapuram Wind 600 41 TN Kamuthi Solar Park Solar 1000 42 KER Kottathara Project Wind 80 43 KER Vettathur Project Wind 80

44 KER Kuyilimala Wind Project Wind 14.25 45 KER Kasargode Solar Project Solar 200

Data not present in draft NEP Vol.2(Trans.)

46 AP Gamesa Renewable Pvt. Ltd.(Kurnool) Wind 350 47 AP Gamesa Renewable Pvt. Ltd.(Dhone) Wind 300 48 KA Ostro Dakshin Power Pvt. Ltd. Wind 300 49 KA Orange Ashok Wind Power Wind 250 50 KA Renew Wind Energy (TN) Pvt. Ltd. Wind 400


(Koppal) 51 TN Inox Wind Infrastructure Services Ltd Wind 500 52 TN Vagarai Suzlon wind farms Wind 200 53 TN Regen Wind Farm (Vagarai) Wind 600 or 384 54 TN Renew Power Ventures Pvt. Ltd.(Karur) Wind 400 56 TN Orange Sironj Wind Power Pvt. Ltd. Wind 200 57 TN Ostro Alpha Wind Pvt. Ltd. Wind 400 58 TN BLP Energy Pvt. Ltd. Wind 250 59 TN Greenmint Power Pvt. Ltd. Wind 200 60 TN Gamesa Renewable Pvt. Ltd.

(Thoothukudi) Wind 400

61 TN Sitac Kabini Renewables Pvt. Ltd. Wind 250 62 TN Gamesa Renewable Pvt. Ltd. (Karur) Wind 200 63 TN Green Infra Wind Energy Ltd. (Tirpur) Wind 250

13.2 In earlier Meetings, the following had been noted:

KSEBL vide letter dated 23.02.2017 had raised certain issues on the approach of wind

generation to leave the STU connectivity to ISTS connectivity and passing over the additional

expenditure to the existing LTA holders.


It was noted that RE schemes are getting modified at times while some are getting dropped

also. TCC had suggested that the RE Projects/evacuation schemes may kindly be reviewed

and updated status communicated. It was observed that timely progress on these schemes

needs to be communicated to SRPC Secretariat, being a critical issue monitored by various

bodies.


13.4 In the OCC Meetings, SRPC/SRLDC had enquired from the States regarding the proposed addition

of Wind/Solar projects in their respective system as given below:

NTPC had been requested to revert on status update with regard to NP Kunta Stage II. In

Andhra Pradesh and Karnataka also, Wind/Solar parks are expected to be come in near future

such as those in Ananthapur and Pavagada.

It was noted that Procedure for RE Framework had already been notified and was available at

NLDC website. States/RE Developers had been requested to ensure that infrastructure to

implement RE Framework either at ISTS/ISTS level was in place from the inception stage itself.

13.5 Transmission System associated for Tumkur Ultra Mega Solar Park (2000 MW)

Transmission

Elements

Line Length

(ckm)/

MVA/MVAR

Capacity

Implem

enting

Agency

Sch

COD

Ant

COD/

Act COD

Constraints/ Remarks

A. Transmission system for connectivity by September 2017

400/220 KV Tumkur

(Pavagada) PS

1 x 500 MVA

Oct 18

PGCIL

report :

Dec 18

31st TCC:

Ready for

charging

Award placed in April

16.

LILO of 400 kV Gooty

–Tumkur

(Vasantnarsapur) D/C

at Pavagada PS

1.72

PGCIL 31st TCC:

Ready for

charging

Award placed in

Jun‟16. Survey had

been completed.

220 kV Line Bays (8

nos) at 400/220 kV

Pavagada PS for solar

31st TCC:

Ready for

charging

8 No. of Line Bays

required


interconnection Bus Reactor at

Pavagada

1 x 125

MVAR

Award placed in April

16.

B. Phase-I : Transmission system for LTA Tumkur Ultra Mega Solar Park (1000 MW) by

September 2017

Pavagada PS - Hiriyur

400 kV D/C line (as

part of Pavagada PS -

Mysore line)

218

PGCIL

Oct 18

PGCIL

report :

Dec 18

31st TCC:

Oct 17

For 400 kV Tumkur –

Mysore line section

routed via Hiriyur S/s.

Award placed in

Jun‟16.

LILO of 400 kV

Bellary Pool – Tumkur

D/C (Quad) (both

circuits)[KPTCL line]

at Pavagada PS*

111

PGCIL 31st TCC:

Oct 17

*KPTCL to complete

Bellary PS – Tumkur

D/C (Quad) by

December- 2016.

Award placed in

Jun‟16.

Augmentation of

400/220 KV Pavagada

Pooling Station

2 x 500 MVA

Award placed in

Apr‟16

C. Phase-II : Transmission system for LTA Tumkur Ultra Mega Solar Park (1000 MW) by

September 2018

Hiriyur–Mysore 400

kV D/C line

412

Oct 18 Jan 2019 One ckt would be

connected with one ckt

of Tumkur-Hiriyur to

make Tumkur-Mysore

direct line

Fixed series Capacitor

(40%) on 400 kV

Pavagada - Tumkur

D/C (Quad) at

Pavagada PS

Augmentation of

transformer at 400/220

kV Pavagada PS

2 x 500 MVA

Dec 2018 Award placed in April

2016

2nd

Bus Reactor at

Tumkur (Pavgada) PS

1 x 125

MVAR


2016

Third 400/220 kV

MVA transformer at

Tumkur

(Vasantnarsapur)

1 x 500 MVA


2016

Switchable Line

Reactor at Mysore end

of Hiriyur-Mysore D/C

for each circuit

1 x 80

MVAR

D. Additional ATS for Tumkur(Pavagada), to match with the commissioning of Devanahalli

SS of KPTCL

400 kV Pavagada PS -

Devanahalli (KPTCL)

D/C (Quad) line with

some portion on multi

circuit towers

125 KPTCL would

complete establishment

of 400/220 kV

substation at

Devanahalli including

inter-linking 400 kV

and 220 kV lines


before Phase-II at Ultra

Mega Solar Power

Park.

13.5.1 In earlier Meetings, the following had been noted:

KPTCL had informed that 500 MW would be coming up by June 2017. Second module of

500 MW was expected by September 2017. Project was scheduled to be completed by

September 2018.

PGCIL had informed that evacuation would be ensured matching with generation modules

coming up. They were focusing on completing the Pavagada SS and LILO of Gooty-Tumkur

line at Pavagada SS.

13.6 PGCIL had filed Petition No. 145/MP/2017 Petition under Section 79(1)(f) of the Electricity Act,

2003 and Regulation 33 B (Power to Remove Difficulty) of the CERC (Grant of Connectivity,

Long-term Access and Medium-term Open Access in inter-State Transmission and related

matters), Regulations, 2009 along with Regulation 111 (Inherent Powers) of the CERC (Conduct

of Business) Regulations, 1999 read with Regulation 2(3) of the CERC (Payment of Fees)

Regulations, seeking directions for preventing underutilization of bays for Connectivity granted to

Wind/Solar generation projects. In the ROP (for date of hearing 27.07.2017), Commission had

directed to list the Petition for hearing on maintainability as well as on merits on 16.8.2017. On

the issue of squatting of connectivity, following was suggested:

I. A mechanism of giving priority is required to be evolved while granting connectivity. Criteria

for prioritizing could be acquisition of land, signing of PPA, obtaining financial closure,

placement of purchase orders for equipment, start of project work, etc.

II. To stop non-serious players applying connectivity, a provision of submitting bank-guarantee

along with the connectivity application may be considered. It could be minimum Rs. 5 Lakh

per MW.

III.Considering the low gestation period of wind power projects the connectivity should not be

granted for the projects indicating commissioning of projects beyond a period of three years

from the date of connectivity application.

IV. Periodic review of projects granted connectivity should be carried out and connectivity should

be revoked for not achieving certain milestones that are required for development of wind

power projects. Suggested milestones are as under:

a. Within a period of 12 months from the date of grant of connectivity, the applicant has to

acquire at least 50% of land required for the project and also sign bay implementation

agreement & deposit advance for bays implementation at ISTS substation.

b. Within a period of 18 months from the date of grant of connectivity, the applicant has to

sign PPA for sale of 100% power from his project.

c. Within a period of 24 months from the date of grant of connectivity, the applicant has to

complete the financial closure.

10. The mechanism suggested above discouraging squatting of connectivity to be made applicable for

both new and applications pending for grant of connectivity.

11. For projects already granted connectivity, periodic review of projects as suggested above should

be applicable, however, in such cases the achievement of required milestones will be from the date

of issue of final order by Hon‟ble CERC in this regard.


12. In case of solar, most of the projects are coming in solar parks. For solar parks there are separate

provisions for grant of connectivity and practically there is no issue of squatting.

13.7 Implementation of the Ultra Mega Solar Power parks having capacity of 500 MW and above

under National Solar Mission

13.7.1 TANGEDCO vide letter dated 16.08.2017 (refer Annexure-XXIX) had stated that as per

guidelines if the capital expenditure for the evacuation network is high, then a separate proposal

may be considered for funding from National Clean Energy Fund (NCEF), Green Corridor

Programme or any other source. It was stated that CTU/PGCIL and implementing agencies in the

state without following the guidelines are trying to pass on the financial burden to other DICs

without availing the grant/fund. It was stated that the matter regarding assigning of responsibility

of monitoring the funding process to the implementing agency is to be in place to avoid passing

on the burden to other DICs.


TANGEDCO had stated that MNRE was giving financial assistance for Ultra Mega Solar

Power Parks having capacity of 500 MW and above in the form of grants and arranging loans

through NCEF/Green Corridor programme, if the capital expenditure is higher. It also

arranged funds through bilateral and multilateral financial institutions. One of the objectives

was to ensure that transmission evacuation planned would involve minimum transmission

and wheeling charges. CTU/Implementing agencies were not following these guidelines and

thus financial burden was being passed on to other Discoms since there was no information

on availing the grant/funds. There needed to be some monitoring agency to crosscheck the

funding process.

On a query about grant for intra-state transmission projects linked with Solar evacuation,

CTU had clarified that Rs 20 lakhs/MW grant is envisaged for an Ultra Mega Solar Power

Project under Central Financial Assistance (CFA). 60% is for Solar Park Developer (SPD)

and 40% for transmission system for evacuation which could be either by CTU or STU. The

installed capacity is 4,750 MW and thus grant worked out to Rs 380 crores. They have

already applied for CFA (Rs 190 crores) for four projects NP Kunta, Rewa, Tumkur &

Bhadla while balance (Rs 190 crores) would be applied after completion of the project.

PGCIL was taking up evacuation for only 8 UMSPPs as per directives of GoI. For NP Kunta

and Pavagada (Tumkur).The Capex was around Rs 1,200 crores. Only cost beyond the grant

would be included in the PoC and not loaded to the Wind/Solar developers as per the GoI

Order, Tariff Policy and CERC Order.

Waiver of transmission charges was only in respect of such projects entering into PPA with

Discoms for compliance of their RPO.

NPC had also clarified that grant was envisaged for the 20,000 MW identified Solar Parks by

MNRE. Out of 34 Solar Projects, 13 are ISTS while 21 are intra-state projects.


13.8 Inclusion of the transmission system for Solar Power evacuation under PoC and its

implication on CERC (Sharing of Inter State Transmission Charges and Losses)

Regulations, 2010

13.8.1 TANGEDCO vide letter dated 16.08.2017 (refer Annexure-XXIX) had stated that the present


methodology for computation of POC charges does not consider solar injection nodes for

perturbation under marginal participation method. Hence, there will be huge error in allocating

transmission charges due to addition of evacuation as well as connectivity system for solar

power parks of grid scale capacity. Also, the LTA quantum of solar power parks is not included

in computation of POC charges which leads to exemption of host state from the burden and thus,

the burden is passed on to other DICs. It had been suggested that the Sharing Regulations are to

be re-visited and the license of Webnet software be supplied to all DICs for validation purposes.


TANGEDCO had stated that Sharing Regulations, 2010 does not take into consideration

evacuation of Solar Power and its impact on PoC. Present methodology of computation of

PoC charges does not consider solar injection nodes under perturbation in marginal

participation. Connectivity and additional evacuation for grid scale Solar would create huge

error. The host state is exempt from PoC and the burden is passed on to other DICs. The

license of Webnet software should be made available to all DICs and this would be helpful in

Validation Committee Meetings.

CTU had stated that the issue could be addressed by NLDC since they are making the PoC

computations.

NLDC had informed that regarding sharing of Webnet software, the DIC would need to

approach Hon‟ble CERC.

It was noted that though Wind / Solar are exempt from transmission charges, but the manner

in which it is captured in PoC computation needed further understanding. Solar LTAs are not

considered in the denominator for arriving slab rates. From the 3rd

Amendment of PoC, it is

also apparent that transmission charges payable by DIC is not function of LTA. Most likely

solar/wind injection is also being treated like any other injection node. How the transmission

charges are being waived is not understood? Generally, loads near the identified system for

wind/solar would be bearing the charges.

NPC had observed that single case for PoC computations may need to be expanded. It was to

be appreciated that Solar generation would be nil during evening peak hours.

It was noted that Hon‟ble CERC had constituted a Task Force to review, „Framework of

Point of Connection (PoC) charges‟. Terms of Reference of the Committee are as follows:

a) To critically examine the efficacy of the existing PoC mechanism to see whether the

mechanism has served its purpose as enshrined in Tariff Policy namely sensitive to

distance, direction and quantum of flow;

b) The role of the existing mechanism in improving the power market;

c) Deficiency in the existing mechanism if any, and in the light of issues and concerns of

various stakeholders;

d) To assess the status of availability of data and data telemetry in order to facilitate shifting

towards actual scenario than the estimated scenario as done currently;

e) Suggest modifications required in the existing mechanism in due consideration of future

market scenario, large scale capacity addition of renewable, introduction of GNA concept

for transmission planning, introduction of ancillary services and reserves, supported by

international experience in this regard;

f) Specify Reliability benefit in a large connected grid and provide methodology for

determination of quantum of Reliability Support Charges and it‟s Sharing by constituents


and to provide Methodology of Sharing of HVDC Charges by constituents;

g) Final Recommendations on Transmission pricing;

h) In addition, the Task force was also to study the following and make recommendations to

the Commission:

i. To assess the utilization of transmission system and suggest measures to improve the

utilization of transmission system;

ii. To assess the reactive power requirement in integrated grid and examine the adequacy

of available reactive power management resources.

iii. To assess the available transfer capability and the measures to improve the same;

iv. Any other relevant issue.

The Report was to be submitted within six months of the Order. Last date of submission for

comments/suggestions had been extended till 31st August 2017.

It was not understood how in the present methodology of drawal based allocation of costs,

the exemption for Solar and Wind transmission charges had been factored.

It had been agreed that Chairperson, SRPC would be kindly requested to take up common

issues in this regard with Hon‟ble CERC.

All DICs had been suggested to take specific issues / suggestions with the Task Force.


14. REQUEST TO ISSUE CERTIFICATE FOR CLAIMING ADDITIONAL ROE AS PER CERC

GUIDELINES IN RESPECT OF TRANSMISSION ELEMENTS ASSOCIATED WITH THE

FOLLOWING SYSTEMS

14.1 Powergrid, SRTS-I vide letter dated 12.05.2017 (Annexure-XXXI) had requested for issuance of

certificate for claiming additional RoE as per CERC guidelines in respect of Transmission elements

associated with the following Systems

I. System strengthening in Southern Region for import of Power from Eastern Region

System had been put into commercial operation w.e.f. 1.2.2017. The DOCO notification was

enclosed. It was also mentioned that Vemagiri GIS substation has been commissioned 9.27

months ahead of CERC completion schedule (Detailed milestones and time line calculation

enclosed).

II. Wardha-Hyderabad 765 kV Link

The system had been put into commercial operation w.e.f. 24.4.2017. The DOCO notification was

enclosed. It was mentioned that Wardha-Nizamabad 765 kV D/C Line and 765/400 kV

Nizamabad GIS has been commissioned 13.17 and 9.17 months ahead of CERC completion

schedule (Detailed milestones and time line calculation enclosed). Consent of beneficiaries for the

commissioning has been obtained in the 31st Meeting of SRPC held on 25.2.2017 at Bengaluru.

PGCIL had requested SRPC Secretariat to provide the necessary certificate as per Clause 24.2 iii

of CERC Tariff Regulation for 2014-19 Block, enabling POWERGRID get additional 0.5% ROE.

14.2 SRPC vide letter dated 24.5.2017(available in SRPC website) had certified that elements mentioned

above (Wardha-Nizamabad sector) were fulfilling provisions of Regulations 24.2 iii of CERC Tariff

Regulation 2014. Subsequently, OCC had recommended that since Vemagiri scheme too was

commissioned within the scheduled date, it too may be recommended for additional ROE.


14.3 This matter had been put up for SRPC approval for additional ROE for the Vemagiri system.

TCC deliberations

14.4 TCC recommended for approval of SRPC for additional ROE in respect of the Vemagiri system.

SRPC deliberations

14.5 SRPC approved the same.

14.6 Default in payment of outstanding dues by beneficiaries

POWERGRID vide letter dated 4th

August 2017 (Ref Annexure-XI) have intimated that there was

default in payment in respect of Simhapuri Energy Limited, CESC, UPCL, KSK Mahanadi and

Telangana. It had been requested that the concerned utilities may liquidate the outstanding balance

on priority.

The following had been deliberated in the TCC Meeting:

TSTRANSCO informed that the dues would be cleared shortly.

Other utilities were requested to kindly clear the dues at the earliest.


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

15.1 Krishnapatnam UMPP (6x660 MW)

15.1.1 Following had been noted in earlier Meetings of SRPC:

Matter was sub-judice in High Court of Delhi.

Progress of Krishnapatnam UMPP had been uploaded in MoP website with the observation

„The project was handed over to Reliance Power Ltd. on 29.01.2008. The developer has

stopped work at site, citing new regulation of pricing in Indonesia. Lead Procurer namely

Andhra Pradesh South Power Distribution Company (APSPDCL) has issued termination

notice to Coastal Andhra Power Ltd (CAPL). The case is subjudice in division bench, Delhi

High Court.‟

APTRANSCO had informed that in the last Procurers Meeting, lead procurer (APSPDCL)

had been suggested to obtain legal opinion on APTEL Order and ongoing legal proceedings.

APTRANSCO had requested consent of other procurers to seek legal opinion.

The following was noted in the TCC:

AP had informed that as per decision of the procurers, they were contemplating a Special

Leave Petition (SLP) before Hon‟ble Supreme Court to issue directions for early disposal.

SRPC deliberations

CMD, APTRANSCO 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 would be 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.

15.2 Cheyyur UMPP (4,000MW)

15.2.1 In earlier Meetings, following had been noted:

CTU had informed that this project had been identified under „Plug and Play Mode‟ and new


bids would be called.

Progress of Cheyyur UMPP has been uploaded in MoP website with the observation „The

site at Cheyyur in Kanchipuram District in Tamil Nadu has been identified along with

captive port at Panaiyur village. Request for Qualification (RfQ) and Request for Proposal

(RfP) issued in 2013 were withdrawn. Fresh RfQ and RfP are to be issued after the

finalization of Standard Bidding Documents.‟

TANGEDCO had informed that land acquisition was over. In case the bidding process is

getting delayed they were willing to take the project by themselves.

The following was noted in the TCC Meeting:

CTU informed that they had closed the LTA application.


15.3 Schedule of synchronizing/commissioning of the new projects of NTPC, NLC, NPCIL, and

BHAVINI & UMPP is furnished below:

Station Unit

Installed

Capacity

MW

Scheduled date of

synchronizing /

commissioning

Remarks

NTPC

Kudgi TPS

Stage-I

I,II,

III

3 x 800=

2400

Unit-I

CoD from

31.07.2017

Unit-II

31st TCC:

CoD by Sep 2017

Unit–III

31st TCC:

CoD by Dec 2017

NTPC had confirmed that

full DC would be ensured

and there were no

constraints.

1st super critical unit of

NTPC.

Latest technology with

Doosan Boiler and

Toshiba Turbine

31st TCC:

TSTRANSCO had enquired about the generation availability since there

were some reported coal linkage issues at Kudgi. Full Generation was

required in March / April 2018.

NTPC had informed that around 12-13 MU /day per unit generation was

expected. Full generation from all the three units was expected from

April 2018 onwards. Presently the coal was being availed from Singareni

and the required coal was being received. Generation schedule details

would be communicated in the next OCC.

Telangana STPP

Phase I

2 x 800 31st TCC:

U-I CoD Jan 2020

U-2 CoD July 2020

Boiler : BHEL

Turbine: Alstom

BOP: Tata Projects

Boiler columns have been

erected. Action of shifting of

the towers has been

initiated.

It was a prestigious and fast

track project.


Pudimadaka AP 4 x 1000 52 Months from Zero

Date

85% share to AP.

Zero date yet to be finalized.

AP had requested NTPC to

firm up the zero date at the

earliest.

31st TCC:

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

two months, the status would be communicated.

CTU informed that there was no connectivity / LTA application pending

with them.

NLC

New Thermal

Power Project

I 500 31st TCC:

April 2018

II 500 31st TCC:

April 2018

CTU had informed that for evacuation LILO of Neyveli - Puducherry

and 400 kV D/C to Araliyur lines are planned. NLC had applied for

LTA of 340 MW which could be managed with the LILO of Neyveli –

Puducherry. Balance 600 MW would be catered by 230 kV system of

TANTRANSCO.

31st TCC:

Araliyur S/S being developed by TANTRANSCO was awarded to BHEL,

works were under progress and expected by March 2019.

230 kV system was expected by March 2018.

TANTRANSCO requested for space for 400 kV S/S in NLC. NLC stated

that the space constraints had already been informed to TANTRANSCO.

Any new 400 kV SS would require Standing Committee approval also.

NLC and TANTRANSCO would mutually discuss on this issue.

TANTRANSCO stated that they would take up the requirement in

Standing Committee.

32nd

SRPC:

Director (P), NLC stated that power evacuation system needed to be

made ready.

TANTRANSCO assured that the 230 kV system would be ready by March

2018.

BHAVINI

Kalpakkam

(PFBR)

I 500 Synchronization by

2017-18

COD by 2017-18

31st TCC:

CTU had informed that the evacuation system was completed in 2012

and as per the CERC Order, transmission charges are to be paid by

BHAVINI. The charges were not being paid by BHAVINI and the dues

had accumulated to Rs 88 crores.

NPCIL informed that BHAVINI was a separate Corporation under DAE.

NPCIL was however kindly requested to convey the concern of CTU to

BHAVINI.


UMPP

Krishnapatnam 3960

(6 x 660)

APEPDCL and PCKL had

taken steps with their legal

counsel to expedite the

hearing before Honorable

High Court of Delhi

Cheyyur 4000 New bids would be called


16. NEW PROJECTS OF STATE SECTOR & IPP

16.1 Updated status of new projects of State sector is furnished below:

Sl

No

Name of project Located

in

Capacity

in MW

Commissioning Schedule

/Remarks

1 Rayalaseema TPS ST-IV AP 1 x 600 Synchronization in 2017-18

COD in 2017-18

2 Dr. NTTPS, Vijayawada AP 1 x 800 June 2019

3 Krishnapatnam Stage II

(U3)

AP 1 x 800 2017-18

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

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 2018-19

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

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

U3 – 5 2021

16.2 Updated status of new projects of IPPs is furnished below:

Sl

No.

Name of project Located

in

Capacity

in MW

Commissioning Schedule

/Remarks

1 Meenakshi PH-II AP 2 x 350 2017-18

Untied: 640 MW

2 East Coast Energy

Thermal

AP 2 x 660

2017-18

AP : 300 MW


3 Thermal Powertech

(TPCIL) Unit-III

AP 1 x 660

2017-18

5 Godhna TPP, Janjir –

Champa Dist,

Chhattisgarh

For

KAR

2 x 800 2017-18

17. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY

17.1 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 operationalized 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.

17.2 In earlier Meetings the following had been noted:

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

Members. It was discussed in the Stake holders Meeting held on 15.03.2016 where all

generators had participated. NTPC, Dadri Stage-II was decided for Pilot Project keeping in

view the high variable cost, load center plant and since it is easy and economical to keep

spinning reserve. LOA for Dadri Pilot Project has been placed on 18th

Jan 2017 with time

schedule of 4 months. Since this had commercial implications, the issue was being discussed

with NTPC, Dadri and Hon‟ble CERC would be approached for appropriate orders. Though

date for implementation was 01.04.2017, but being a new project, Hon‟ble CERC had been

approached appraising all the difficulties. It had therefore been suggested that Pilot project

would be taken up first and after getting experience and submitting the report comprehensive

AGC installation could be taken up.

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

Kunta would be taken up.

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

for technical compliance to meet AGC requirements. For all plants, control signals would be

centrally transmitted from NLDC to the AGC software.


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

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

SRPC had informed that Hon‟ble CERC in its Order in respect of Petition No. 65/MP/2014

dated 13.2.2017 had stated the following:

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

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

experience gained from RRAS operations, POSOCO is expected to submit a detailed procedure

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

Committee on Spinning Reserve. Hence, in our view, there is no requirement to engage an

international consultant to study and recommend the road map for introduction of constant

frequency operation/secondary control.‟

17.3 NLDC had filed Petition No. 79/RC/2017 in the matter of, „Petition for implementation of

Automatic Generation Control (AGC) pilot project.‟ In the ROP (date of hearing 18.07.2017)

Commission had admitted the petition and directed to issue notice to the Respondents. The

Commission directed the Petitioner to upload the detailed modus operandi on Operationalization of

Spinning Reserves on its website and seek comments from the stakeholders by 11.8.2017 and file

the comments received from stakeholders within two weeks thereafter. The petition had been listed

for hearing on 21.9.2017.


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

(Presentation copy enclosed at Annexure-XXXII). Unit-5 & 6 had responded well and based

on that they had filed the Petition.

NLDC had informed that a team had visited Simhadri and it was noted that it was feasible to

extend/incorporate AGC signals. They had taken up the issue further with NTPC HQ.

SRLDC team had visited NP Kunta on 27th

June 2017 (including participation from NTPC,

APSPCL, PGCIL, APSLDC, APTRANSCO, M/s ABB, M/s Hitachi and M/s BHEL) and on

25th

July 2017 (including participation from NLDC, NTPC, APSPCL and M/s Siemens) in

which technical feasibility was studied / assessed. Post NP Kunta visit, a Meeting was held at

SRLDC on 26th

July 2017 with participation from NLDC and M/s Siemens (Presentation copy

enclosed at Annexure-XXXIII). Since it involved more stake holders (SPD, NTPC,

TRANSCO etc) they would discuss the matter with them also.

NLDC had informed that detailed modus operandi on Operationalization of Spinning Reserves

had been uploaded on its website. Comments had been sought from the stakeholders and the

date had been extended up to 25th

August 2017.

SRPC deliberations

NLDC informed the Team had visited Simhadri and it was possible to extend AGC signal. The

details had been communicated to NTC HQ and further discussions were likely to take place

shortly. Team from NLDC/SRLDC had also visited NP Kunta and a meeting of the stakeholders

would be called.


18. INCLUSION OF DRAWAL OF MAHE IN REA


18.1 In the 32nd

Meeting of CCM it had been decided that power drawal of Mahe Region of UT of

Puducherry would be included in REA of Southern Region from 7th

Nov 2016. In the 31st SRPC

Meeting, CMD, KSEBL had agreed with the proposal of SRPC Secretariat, in principle, since it

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

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

18.2 In the CC Meeting, the following had been noted:

KSEBL had informed the forum that only after termination of HT consumer contract, it can be

considered as a drawal point in REA. For the termination of HT consumer, they had to clear

the pending dues.

Puducherry ED had requested KSEBL to adjust security deposit amount with them.

Puducherry had also informed that in this regard, KSEBL had not responded and additionally,

they had raised another bill for Rs 3.5 Crores recently.

Puducherry ED had informed that they had addressed a letter to KSEBL regarding the pending

dues to KSEBL.


Director (T&SO), KSEBL had stated that they were agreeing to the proposal but some dues

were to be cleared by PED.

SE-I, PED had stated that the dues being pursued by KSEBL was for excess demand from the

period since 1995 which had been claimed only now. The law department was weighing the

claims as per provisions of the Act and clearance had not been received. Law department was

not giving clearance for payment of the dues since claims had been made belatedly. Since it

could take some time to obtain final clearance from Government, pending the payment,

KSEBL and PED could progress in this regard to ensure that migration to REA takes place

from 01.09.2017.

Director (T&SO), KSEBL had stated that the dues need to be cleared by PED before shifting

to REA. However, the status would be updated to KSEB Board for its consideration.

SRPC deliberations

18.4 SE-I, PED informed that they were in final stage of settlement and hopefully they would migrate

to REA by next month.

18.5 CMD, KSEBL stated that there were some dues to be cleared but subject to that matter would be

considered. PED should take necessary action to settle the old payment issues at an early date.

19. ISSUES IN RESPECT OF NPCIL

19.1 Balance dues from Beneficiaries

NPCIL had furnished statement of outstanding dues (Annexure-XXXIV) of Southern Region

beneficiaries as on 30.06.2017. Since outstanding dues in respect of TNEB, Karnataka,

APTRANSCO and TELANGANA were considerably high, it had been requested to include the

same as the Agenda Item of NPCIL for discussions.

TCC deliberations

MAPS/NPCIL had again requested for the dues to be cleared at the earliest.

TANGEDCO had informed that dues up to March 2017 had already been cleared and with

regard to the other dues, matter would be pursued.


TS/PCKL had informed that the dues would be cleared by September 2017.

AP had informed that earlier dues had been cleared and was pending for May & June 2017,

which too would be cleared.

SRPC deliberations

Director (Distribution), TANGEDCO informed that all dues up to March 2017 had been

cleared. The pending dues for MAPS was Rs. 68.54 Crores, for Kaiga GS Rs. 138.71 Crores

while for KKNPP Rs. 579.91 Crores and the same would be cleared within 2 months.

MAPS/NPCIL informed that KKNPP dues itself were about Rs 921 Crores up to July 2017

19.2 Extension of 400 kV KKNPP – Tirunelveli line to Tuticorin PS

SR-II, PGCIL vide letter dated 18.07.2017 (Annexure-XXXV) had mentioned about the

commissioning of „Extension of Kudankulam APP – Tirunelveli 400 kV (Quad) D/C line to

Tuticorin PS along with associated bays at Tuticorin PS under connectivity for Kudankulam 3&4 (2

x 1000MW) with interstate transmission system‟. The subject had been approved in the 36th

SCPSPSR (04.09.2013) and also in 23rd

SRPC (26.10.2013). This arrangement would facilitate two

termination points‟ viz. Tirunelveli and Tuticorin PS for evacuation of Kudankulam 1 & 2 and

avoid operational difficulties in case of any bus fault at either Tirunelveli or Tuticorin PS.

TCC deliberations

MAPS/NPCIL had stated that the same could be taken up.

It was agreed that this matter would also be discussed in the Special Meeting to be convened

shortly.

SRPC deliberations

CTU informed that Kudankulam APP – Tirunelveli 400 kV (Quad) D/C line to Tuticorin PS

was scheduled for September 2017 and the same can be agreed for preponement. This was

planned to avoid the outage of both the units in case of bus fault and would help improve the

reliability.

SRPC concurred for the preponement.

19.3 Black start mock drill for Nuclear Power Plants

In earlier Meetings, the following had been noted:

Stress was laid on documentation regarding house load operation of Nuclear

Units/methodology for bringing the units on bar after house load operation/Procedure for

Black Start Operation. The same would be incorporated in the SRLDC‟s BSRP document.

MAPS had informed that low frequency set points would be retained. High frequency set

points for house load operation would be examined.

KKNPP BSRP Mock drill was planned in October 2017.

KGS had informed that BSRP procedure is already available. Mock Drill to be carried out

using 220 kV system and whenever KGS Unit 1 or 2 are out, Drill could be planned.

TCC deliberations

MAPS/NPCIL had informed that mock drill could be taken up in MAPS and Kaiga GS

during the next BSD.



19.4 A/R for MAPS/BHAVINI lines

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

MAPS had informed that they required 15 numbers of CVTs and requested TANTRANSCO to

spare them. As committed earlier, they would comply with CERC order in respect of

providing of CVTs and would enable A/R by July 2017. Parallely, they had initiated action to

purchase the CVTs.

TCC deliberations

MAPS/NPCIL had informed that A/R for BHAVINI lines had been completed.

A/R for MAPS lines would be completed by December 2017. It had been pointed out that in

compliance of the CERC Order, MAPS had earlier committed enabling of A/R by July 2017.

MAPS had informed that retendering had been taken up.


19.5 Status of 2 x 125 MVAR reactors at Kaiga GS

New reactors were likely to come up only during 2019.

KGS / NPCIL to interact with SR-II PGCIL for utilizing the Regional spare reactor.

TCC deliberations

MAPS/NPCIL had informed that tendering process was underway and the reactors were

expected by December 2019.


19.6 Reactive requirement for KKNPP Phase-II unit

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

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

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

earliest.

SRPC & SRLDC had stated that limitation of absorption by Stage-2 units needs to be taken

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

2 bus reactors at KKNPP-I were under prolonged outage. Expected to be back by December

2017 & Feb 2018.

TCC deliberations

MAPS/NPCIL had informed that the schedule for Phase-II Units was being finalized. The

Reactor requirements would be taken up with CTU.

One bus reactor under prolonged outage would come by December 2017 while other

would come by June 2018.


19.7 Planned maintenance of NPCIL Units

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

had assured that to the extent possible, shutdowns would be planned during the period May

to December each year.

TANTRANSCO vide letter dated 23.03.2017 (Annexure-XXXVI) had stated that it is

regretted that despite repeated request from TANTRANSCO, MAPS had availed shutdown

of Unit -1 from 19.03.2017. TANTRANSCO had requested that SRPC may kindly look into

the matter and see that NPCIL, NTPC and NLC Stations plan their shutdown/AOH

programme in high wind season from June-September months and during lean demand

period from November-December months in future in the interest of SR constituents.


TCC deliberations

MAPS/NPCIL had informed that the schedule for the unit was from 01st March 2017 but

they could obtain AERB approval for extension by a few days. The shutdown was thus

availed from 19th

March 2017. Certain surveillance tests were to be taken up. They assured

that MAPS and Kaiga GS would plan unit shutdown only during May to December each

year.

KKNPP Unit-I was expected to come back by month end. In respect of Unit-II, OEM

wanted to conduct further tests on the generator and it could take another one month or so

for it come back on bars.

TANTRANSCO/SRLDC had stated that both the KKNPP units should be back by Oct 2017

since the loads pickup.

SRPC deliberations


MAPS/NPCIL assured that planned maintenance would be planned only between May to

December each year.

MAPS/NPCIL assured that Unit-I at KKNPP would come up by month end while unit II

would come back by end September 2017.

19.8 MVAR absorption at KGS

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

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

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

Presently, around 60 MVAR & 10 MVAR injections from Unit 3 & Unit 4 were being

observed.

As a long term measure, NPCIL was planning to replace the generator itself.

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

precautions etc was yet to be furnished by NPCIL.

MVAR Testing at Kaiga GS had been planned during August 2017.

TCC deliberations

MAPS/NPCIL had informed that there were certain technical difficulties and other

generators of similar make such as RAPS were also following similar injection pattern.

SRLDC had pointed out that MVAR injection at high voltage needs to be reduced.

Regarding MVAR testing at Kaiga GS, MAPS/NPCIL informed that though 29.08.2017 was

agreed in the OCC, the site was under discussion with designer and the date would be

confirmed subsequently.

SRLDC had clarified that this was an ongoing exercise and currently more than 30 units in

SR had already been tested for MVAR interchange.


20. COMMUNICATION REQUIREMENT DURING NATURAL DISASTERS

20.1 During deliberations on experience learnt during Vardha cyclone it had been agreed that an Expert

Committee comprising of Communication Engineers including representation from CEA and LD

& C, PGCIL would study communication requirements for ensuring data/voice to RLDC/SLDC

during Natural Disasters.

20.2 Subsequently, MS, SRPC vide letter dated 10.07.2017 (Annexure-XXXVII) had taken up this


matter with Chief Engineer (LD&T) Division, CEA.


21. STATUS OF GENERATION IN ISGS

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

in earlier Meetings of SRPC. Level of generation of some ISG stations is given below:


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

PLF would improve from March 2017 onwards.

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

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

MCL had stated that NTECL was being given additional coal from ECL & CCL and supply

from MCL would also be improved. There were no coal supply issues at IB, however rake

issues persisted. Since coal stock at NTECL was under critical category, MCL headquarters /

CIL were taking necessary initiatives to augment coal stock from other subsidiaries.

NTECL Unit-3 was out from 04.06.2017


MS, SRPC had informed that cumulative availability up to July 2017 in respect of NLC TS-II

Exp was only 58.9%. For NTPL the same was 78.8 % while for Vallur it was 80.7%.

NLC had informed that they were in the process of stabilization and some small minor

problems were to be attended. They had demonstrated 500 MW in last month and were putting

all efforts and hopeful of improved performance.

NTPL had informed that they had availed two overhauls and performance would increase.

Presently, the availability was 100%.

NTECL had informed that Unit-3 was expected back by 15th

November 2017.

SRPC deliberations

21.4 Director (P), NLC informed that while refractory problems had been rectified, some boiler tube

leakages were surfacing. They had taken up the matter with M/s BHEL and some modification had

been suggested. After material arrival, works would be taken up and reliability could increase

within next 3-4 months.

22. REVIEW OF ULDC / SCADA/COMMUNICATION

22.1 Status of pending items is as follows:

Station Feb-17 Mar-17 Apr-17 May-17 June-17 July-17

NTECL,

Vallur

Generation in MU 744.06 950.53 816.49 856.47 537.42 557.58

PLF 73.82 85.17 75.6 76.74 49.76 49.96

NTPL,

Tuticorin

Generation in MU 507.11 563.21 540.81 498.84 275.28 566.10

PLF 75.46 75.7 75.11 67.05 38.23 76.09

NLC TS II

Exp

Generation in MU 154.48 76.29 254.79 173.38 182.00 153.90

PLF 45.98 20.51 70.78 46.61 50.56 41.37


S.No Issue Action Plan

1

Meeting with M/s

ALSTOM regarding AMC

issues, punch points

Alstom had completed pending works except some of the

on-site training modules, for which schedule was given

Alstom to complete by September 2017. Tentative

recovery rates had been finalized and communicated to

constituents. However, the recovery rates have been put

up for approval.

8.5 In the OCC Meeting, KSEBL had expressed concern that for SCADA system M/s GE

had withdrawn all service engineers from the site. PGCIL was requested to take up the

issue with M/s GE. There were some issues which are to be resolved from both sides but

withdrawal of service by M/s GE puts system security under threat.

8.6 31st TCC:

8.7 SRLDC informed that all trainings have been completed.

8.8 PGCIL informed that the recovery part has been approved by them and has been

communicated to the constituents in last week.

8.9 KSEBL informed that PGCIL has communicated a figure of Rs 9,74,398 which has to be

deducted but the breakup of how the figure was arrived was required. The amount to be

deducted for delay in commissioning was also required to be communicated.

8.10 SR-II informed that once the project is completed then only the deduction for the delay

can be worked out.

8.11 SR-I informed that for delay they had requested AP & TS for the amount to be deducted

so that the contract could be closed.

8.12 TSTRANSCO informed that they had requested for modification in EMS package which

they would be taking up as a separate order. PGCIL was requested to convene a meeting

with M/s Alstom and TSTRANSCO.

8.13 TSTRANSCO informed that they had requested for an estimate for backup SLDC. PGCIL

was requested to expedite. PGCIL informed that they had communicated it to their CC.

2 ICCP link between

RTAMC and SRLDC

Link is established and database tables had been

exchanged. ICCP association was in progress by SRLDC

and NTAMC/Manesar. Data to be exchanged had been

finalized.

8.14 In the OCC Meeting, SR I had informed that the issue of ICCP link between RTAMC

and SRLDC was raised in a meeting held at Delhi and a Meeting was suggested by

RTAMC between ALSTOM, SRLDC, RTAMC and NTAMC.

3 Data discrepancies in

ISGS/IPP/PGCIL/STUs

Data discrepancy was being updated and shared

fortnightly.

Fresh list of points received from SRLDC on 05.07.2017

and same shall be attended by July end.

4 Providing additional RTU

at NTPC Talcher

RTU procurement was under progress by NTPC

5 Protection coupler

replacement for

Kayamkulam Transmission

system

Letter from KSEBL received. Approval for the depository

amount to be paid to KSEBL is under process. PGCIL

assets shall be borne by PGCIL at the rates of LOA to be

placed by M/s KSEBL. KSEBL to examine the option of

buyback of the old panels to be looked into or handover

the panels to PGCIL.

6 OPGW stringing on balance

portion of KPTCL lines

Except Hassan-Santhigrama (7.4 kM) OPGW stringing

completed on all the lines of KPTCL. Because of non-

readiness of direct line, KPTCL recommended executing

the connectivity through 3 different lines of 35 km and the

same may not be possible in the on-going project as the

supplies are completed.


7 Migration of SCADA

periphery in line with SEM

AP & TS: Migrated on 09.05.2017

TN: Migrated on 08.06.2017

KER : Migrated on 15.02.2017

KAR : Migrated on 08.06.2017

8 SCADA Data failure

Protocol

RTU not reporting/data failure would be communicated

to the concerned entity/user with a copy to PGCIL.

User would take lead role in getting the issue resolved.

User/SRLDC would ensure necessary verification at

their ends as explained in the training. Parallely,

PGCIL would look into communication issues.

User/SRLDC would appraise PGCIL about the

verification at their end for PGCIL to sort out the

communication issues. Official email ID for SCADA

issues to be created for each entity/User involved for

easier communication and proper delivery of

information.

9 Integration of new elements

in SRLDC/SLDC SCADA

SR I /SRII noted for necessary compliance.

10 Issues with Orange

Exchange

A Meeting was held on 16.03.2017 at SR II Bangalore

and the issues are being addressed. Most of the issues

have been addressed

11 Problems with speech

circuit at NTPC

Ramagundam, NTPL,

Vallur, NLC TS II, NLC TS

II Expansion, LANCO

Stage II, IL & FS

Main reason found for one way speech/disconnections

due to bill not paid.

All constituents required to follow up with their services

providers to make available reliable speech

communication.


22.2 SRLDC had invited attention of the forum that Hon‟ble CERC had brought out Order on Suo moto

Petition 007/SM/2014 dated 29.01.2016 regarding SCADA. It had been directed by Hon‟ble CERC

that NLDC and respective RLDC update the status of telemetry every month on their website.

Persistent non-availability of data from generating stations/substations be taken up in RPC Meeting

for appropriate direction and action. Also, NLDC had been directed to submit user wise latest

telemetry by 31.08.2016. SRLDC had informed that they had started posting this information on

their website.

22.3 Vide E-mail dated 16.06.2017PGCIL SR II (Annexure-XXXVIII) had informed that award had

been placed for supply & installation of DTPC (60 no.) as approved by SRPC. However, there

were many changes subsequently and the requirements got changed. PGCIL had requested that the

final list of locations, where the above new DTPCs are to be installed may kindly be furnished so

as to dispatch to the sites.


MS, SRPC had informed that the issue had been discussed in the last Meeting of PCSC. It had

been agreed that due to space constraint considerations, DTPCs (one end) could be provided at

Kolar, Salem S/S or other PGCIL substation. Since the load points (other end) in the states had


already been identified, the DTPCs could thus be dispatched accordingly.

Communication requirements in this regard would be appropriately considered by PGCIL.


22.5 Video Conferencing facility at SLDCs

Status update is as follows:

AP PUDU

APSLDC informed that they

would be taking up the VC by

themselves. The estimated

amount would be deducted from

the payments due to M/s Alstom.

Puducherry would take up VC

requirement in the financial year 2017-18.

SRPC deliberations

CMD, APTRANSCO informed that M/s Alstom was resolving despite number of intimations;

and they would take it up by themselves and complete by September 2017.

23. URTDSM (PMU) PROJECT IN SOUTHERN REGION

23.1 Hon‟ble CERC in its Order dated 16.09.2016 in the matter of „Approval …….. for grant of

regulatory approval for execution of Unified Real Time Dynamic State Measurement (URTDSM)

Phase-II‟ had stated

„22. It is noticed that URTDSM scheme was approved with the purpose to improve the visibility

and security and to mitigate the probability of grid failure. By considering the present progress of

the Phase-I, the petitioner does not seem to have made adequate efforts to complete the phase-I of

the scheme. The implementation period for phase-I was 2014-15. However, it is still under

implementation. We express our unhappiness with the progress of Phase I of URTDSM scheme to

be implemented by the petitioner. We direct the petitioner to expedite the work of Phase-I of the

scheme so that it may be completed by November 2016 as submitted by the petitioner. Since

substantial progress has not been achieved by the petitioner in phase-I, it may not be appropriate

to grant regulatory approval for implementation of Phase-II of the scheme at this stage.

Accordingly, the petitioner is granted liberty to submit the fresh proposal for grant of regulatory

approval for Phase-II of the scheme in consultation with CEA after implementation of Phase-I

scheme, which would be considered in accordance with law.‟

23.2 Following is the status update in respect of URTDSM Phase-I:

Sl No Activity Status/Remarks

1 Status of URTDSM Project

(SR Portion)

PMUs to be installed in SR as per URTDSM Project

Package–II had further increased from 240 to 270 on

account of commissioning of certain new stations and

additional feeders. (As per LOA-212)

Status

Total

Envisaged

Survey

completed

S/S PMU

SS PMU Installed

SR

I

128

Pending in

Hyderabad,

Khammam

and

20 Supplied: 107

Commissioned:

97

Integrated: 85


Vemagiri.

SR

II

41 142 Completed 39 Supplied: 138

Commissioned:

112

Integrated: 110

Kalamassery integrated. KSEBL to extend the bus

voltage.

Forum expressed concern that project was getting

delayed and requested PGCIL / GE to share

monthly project execution plan up to Sep 2017 and

monthly progress ( installation and integration to

Control Centre) status by end of every month.

2 Contractual amendment

Final Amendment had been issued on 19.05.2017

and system expected to be commissioned by Sep

2017. The analytics part by December 2017

3 Requirement of Auxiliary

Power Supply System (APS)

as per revised BOQ

(excluding input ACDB and

one battery bank of the

proposed two battery banks).

Survey completed. Space in SRLDC is not sufficient

for APS solution under URTDSM project. APS

system not supplied due to space constraint in TN &

SRLDC.

4 Capacity of Battery &

charger

None of the constituents requested 48 V DC power

supply source. Hence this point is not applicable

now.

5 Responsibilities under

Entities

SR-II confirmed that Dismantling of panels, any

civil works etc required to prepare site for installing

APS System was not under the scope of the Project

and thus was in the scope of respective

constituents.

Supply, erection& commissioning of UPS, ACDB

Input &Output panels, Battery Bank and associated

cabling works for establishing APS system was

under the scope of the Project.

Air Conditioning System was required and

Constituents were to make necessary arrangements.

Kerala yet to provide clear site by removing

existing old EMS SCADA system and dismantled

materials.

KPTCL has yet to provide Air-conditioning system

to match with the commissioning schedule i.e.

Sept. 17.

TANTRANSCO yet to provide the earthing

connection point for the panels.

6 Redundancy for PMUs PGCIL confirmed that all PMUs are provided with

redundant communication path and schematic

diagram of communication flow had been shared

with the constituents.

7 SAT procedure FAT completed for all 4 Nos control centers.

Equipment supplied to all 4 Nos control centers

and installation under progress at SRLDC,

Karnataka SLDC & TN SLDC.


8 SR Region Training Training had been firmed up by M/s GE and one

batch training is over.

9 Availability of necessary

communication ports for

connection of servers under

URTDSM

Except TANTRANSCO, all constituents extended

the required communication ports at PDS.

10 Training on Application part Application part is in development stage at IIT,

Mumbai. Would communicate the details in due

course.

11 Update the Drawings Constituents‟ requested PGCIL to update the

Drawings with changes done in the CT/PT/Status

wiring for the PMU system and submit as built

drawing.

PGCIL had informed that it will be submitted on

closure to commissioning.

12 Completion of the

commissioning activity at

each site

M/s Alstom and PGCIL representatives were

requested by constituents to certify the completion

of the commissioning activity at each site.

13 Mandatory spares PGCIL had agreed to furnish the details about the

mandatory spares supplied at each site. Mandatory

spares (servers and switches) supplied at each

control centre where main hardware supplied.

Mandatory spares (servers & switches) supplied

at each control center where main hardware

supplied.


APTRANSCO had requested for shifting of GMR PMU to Urvakonda.

It was noted that in the PCSC Meeting it has been agreed to shift the GMR PMU to NP

Kunta. SRLDC had confirmed that PMU at NP Kunta was very much required. If considered

necessary, the PMU at Konaseema could be shifted to Urvakonda or else it could be covered

in Phase II.

TANTRANSCO would furnish their request for additional PMU requirements in Phase II.

Some constituents suggested location changes for PMU in Phase II, it was noted that PGCIL

has already sought for revised requirement in Phase II.

SRPC deliberations


APTRANSCO stated that Konaseema was not covered in the project.

GMR PMU would be shifted to NP Kunta while shifting from another location could be

considered in respect of Urvakonda.

24. SCHEDULING OF WIND & SOLAR GENERATING PROJECTS HAVING CAPACITY OF

500 MW AND ABOVE

24.1 Hon‟ble CERC vide amendment dated 12th

April, 2017 (Indian Electricity Grid Code – Fifth

Amendment) Regulations, 2017, which came into effect from 1st May, 2017 had amended the

Regulation 6.4.2 (b) as follows:

“The Following generating stations shall come under the respective Regional ISTS control

area and hence the respective RLDC shall coordinate the scheduling of the following


generating Stations:

b) Ultra-Mega Power projects and projects based on wind and solar resources and having

capacity of 500 MW and above”

24.2 It had been requested that details of upcoming wind and solar projects with installed capacity of

more than 500 MW may kindly be intimated to SRPC/SRLDC. This would assist in ensuring

technical / commercial requirement as per CEA/CERC Regulations and also seamless integration

and accounting by SRLDC / SRPC. Following had been noted in the earlier Meetings:

APTRANSCO had expressed concern that if the scheduling responsibility is shifted to

SRLDC, it would be difficult for APSLDC to manage DSM deviations considering intra-day

and seasonal variations of load and RE injection.

Chairperson, SRPC had stated that any load/generation management would require to be

carried out by Discoms. Being regulatory associated; the issue had to be dealt appropriately.

APTRANSCO had been suggested to approach appropriate Commission on the issue, if

deemed fit.


25. TTC/ATC


In the 4th

Meeting of NPC held on 10th

December 2015 (MoM dated 1.1.2016), it had been

decided that to begin with, power system study for assessment of operational limits / power

transfer capability for each state would be done by the concerned RLDC in association with

concerned SLDC. Monthly TTC/ATC would be uploaded by SLDCs in their respective

websites and also communicated to concerned RLDC & NLDC subsequently.

Converged PSSE base cases to be furnished to SRLDC.

25.2 The following is the status in this regard:

State 5

months

LGB

Converged

PSSE Base

case

ATC/TTC

Computation

furnished to

SRLDC

ATC/TTC

Computation

posted on SLDC

website

Nodal

Officer

Status

Study

Group

AP Yes No No No No No

TS Yes Yes No No Yes Yes

KAR Yes Yes-Only

peak

No No No No

TN Yes Yes Yes No Yes Yes

KER Yes Yes Yes No Yes Yes

In the TCC Meeting the following had been noted :

APTRANSCO had informed that nominations for Nodal Officer and Study Group would be

communicated within a month from the new recruitees likely to join next month.

KPTCL had also informed that Nodal Officer and Study Group nominations would be

communicated.

SRPC deliberations

KPTCL informed that Study Group has already been formed and relevant details would be

communicated.



25.3 Enhancement in TTC of Southern Region

25.3.1 In the 31st Meeting, SRPC had suggested NLDC to study the proposals of TCC as given

below:

NLDC was suggested to revive TTC/ATC of 500 MW for 10 hours on Talcher-Kolar HVDC

which had been earlier operational (prior to commissioning of Raichur-Sholapur link).

It was observed that constraint for import of power from NEW grid would be Vemagiri-

Gazuwaka line with the worst credible contingency of N-1 of 765 kV Aurangabad-Sholapur

line. TCC suggested NLDC to consider the SPS on 765 kV Aurangabad-Sholapur D/C line

(could be modified for tripping of one circuit of Aurangabad-Sholapur) while selecting the

worst credible contingency for assessing TTC to SR.

25.3.2 SRPC had taken up the issue with NLDC on restoration of 500 MW of extended mode of

Talcher-Kolar. NLDC vide their letter dated 14.03.2017 had informed that it is difficult to

consider the extended mode (500 MW) of Talcher-Kolar HVDC for the purpose of TTC/ATC.

TSTRANSCO vide letter dated 23.03.2017 had taken up the issue with Secretary Power, MoP.

Chairperson SRPC vide letter dated 18.05.2017(Annexure-XXXIX) had taken up the issue with

Secretary (Power), MoP.


25.4 Revision of SR-WR Corridor, due to 765 kV Seoni-Wardha D/C Shutdown on 19th

and 20th

March 2017

25.4.1 Referring to Revision No.11 of Inter-Regional Corridor at 11:30 hours on 17.03.2017, KSEBL

vide letter dated 17.03.2017 (Annexure-XL) had submitted that NLDC had revised WR-SR

Corridor, stating the reason as shutdown of 765 kV Seoni- Wardha D/C line. It was noted that

the above shut down was not included in the reports of the outages issued by SRLDC for the

month of March 2017. Hence, it was to be concluded that revision of the WR-SR Corridor was

done by NLDC within a short notice. Such immediate revisions in the Inter-regional Corridor

cannot be admitted since it upsets the planning of LGB of utilities.

25.4.2 It was noted with concern that after new elements commissioning in WR, new reasons are being

cited for ATC/TTC curtailment for import to SR. Instead of increase of ATC/TTC as expected,

curtailments were increasing. SRLDC had informed that after commissioning of new elements

in WR, opening of those elements in WR, flow through ER was increasing due to sensitivity.

Limited margins were available on ER link.

25.4.3 It was observed that even after commissioning of many vital IR links, ATC/TTC margin had not

increased as expected. POSOCO may need to examine these aspects in detail.


NLDC informed that 765 kV Seoni- Wardha D/C line shutdown had been approved in

WRPC forum from 03.03.2017 to 10.03.2017. This had to be deferred due to Talcher -

Kolar shutdown during that time. WRTS had requested the shutdown for bay modification


works at Wardha. Since it was deferred outage and linked to construction activities it was

approved.

Confirmation for all Inter-regional shutdowns is being sought two days in advance and

being uploaded also.


25.5 TTC Revision beyond the approved/scheduled time of revival

25.5.1 KSEBL had informed that the Talcher-Kolar Shutdown was approved after detailed

deliberations in two of the OCC Meetings. The proposed shutdown was on continuous basis,

which after deliberations had been revised to three days to ensure revival of TTC during

evening peak hours on daily basis. But NLDC vide revision No 10 dated 10.08.2017 had

curtailed the TTC up to 24 hours though the shutdown was approved up to 1700 hrs

(12.08.2017-14.08.2017). Hence, the objective of allowing three days instead of two days (to

ensure availability during peak hours) was getting lost. On those days, all costly generation in

the state was required to be scheduled and they also had to resort to load shedding. Curtailment

of TTC was uploaded on previous day evening. Due to the stand taken by NLDC, the shutdown

was reverted to 2 days in the OCC. During March, similar shutdown had been availed by

PGCIL and TTC was revised in evening peak hours and lines were revived before scheduled

time.

25.5.2 TSTRANSCO had stated that shutdown had been approved with the condition that it would be

returned on daily basis. But it was later converted up to 24 hrs by NLDC. This information was

not shared with all the states. The states are planning short term purchases up to 00 hrs and lack

of information/delayed information was contributing to uneconomical system operation.

25.5.3 NLDC had stated that there had been a couple of instances of delayed revival and therefore they

would restore TTC only 1-2 hours after restoration. This had happened in 30th

/31st July grid

disturbance. While TTC was getting curtailed up to 00 hrs, actual revival was taking place only

after 1-2 hrs. In case element is not restored in time, Power Exchange curtailment (thousands of

transactions) takes 1 to 1 ½ hrs for implementation and therefore need to be avoided. Number of

revisions also had effect on system security.

25.5.4 After deliberations, it had been urged that PGCIL communicate the revival status at least 2-3

hours before the scheduled revival time. Based on this, NLDC was suggested to restore the TTC

at scheduled revival time in its TTC/ATC declaration on website.

SRPC deliberations

25.5.5 CMD, KSEBL informed that since TTC was revised from 11.08.2017 to 14.08.2017 when

HVDC was down, extreme method of even utilizing naptha based generation (Rs 8/unit) had to

be resorted to. TTC curtailment was not informed in a timely manner and even after


maintenance, TTC was not restored expeditiously. It was not only the financial implication, but

KSEBL was forced to resort to load regulation when the House was in session. Better planning

as well as timely intimation would help KSEBL to plan its purchases judiciously and in LGB

management.

25.5.6 MS, SRPC stated that KSEBL had strongly brought out that curtailment was up to 24 hrs,

though approved shutdown was up to 1700 hrs. It had been agreed that PGCIL would intimate

the status 2-3 hrs prior to the scheduled revival for all elements where Inter Regional TTC was

involved and NLDC could restore the TTC at scheduled revival on its TTC declaration on its

website. During HVDC shutdown availed during March, the TTC was being accordingly revived

during peak hours except on bipole shutdown days.

25.5.7 NLDC also pointed out that ATC release involving PX transactions would be complicated since

in case of any delayed restoration, there would be multiple iterations. Hence they had to take a

prudent call on this matter.

25.5.8 CMD, KSEBL stated that an institutional mechanism with clarity should be put in place.

25.5.9 ED, NLDC stated that they would look into the matter. In the past there had been instances of

delayed revival and any curtailment of PX is a serious issue.

25.5.10 ED, SR-I, PGCIL stated that the decision of TCC needs to be implemented. He assured of all

necessary cooperation on this matter.

25.5.11 After deliberations, SRPC noted that PGCIL would communicate the revival status at least 2-3

hours before scheduled revival time. Based on the status, NLDC was suggested to kindly restore

the TTC at scheduled revival time in its TTC/ATC declaration on website.

26. METHODOLOGY FOR CERTIFICATION OF INTRA-STATE TRANSMISSION LINE

26.1 Methodology for SRPC certification of intra state lines, carrying power to other states, to be

applicable to all the utilities, had been firmed up in the 33rd

Meeting of Commercial Sub

Committee held on 31st January 2017. In the 31

st Meeting, SRPC had approved the TCC

recommendation as given below:

„TCC had concurred with the recommendations of Commercial Committee and placed the same

before SRPC for approval. It was agreed that 50% criteria would be reviewed later after

experience/feedback is available on the issue‟.

26.2 SRPC vide letter dated 19.06.2017 (Annexure-XLI) had certified intrastate lines as per the

Procedure.


27. EMERGENCY RESTORATION SYSTEM (ERS)

27.1 Requirement of ERS had been outlined in MoP letter dated 05.12.2014. CEA vide letter dated

21.07.2017 (Annexure-XLII) had stated that in the Meeting held on 28.06.2017 it had been noted


that ERS were in procurement stage in most of the States and the response from the States was

not very encouraging. Secretary (Security) had sought a note from CEA to take up matter with the

concerned States at the highest level. Status update is given below:

Transmission

Utility

Requirement as

per MoP

Existing Status/Remarks

APTRANSCO 3 2 ERS III-submitted for

approval of PSDF funding.

TSTRANSCO 1 TSTRANSCO informed that

re-floated the tender.

Subsequently, it would be

taken up for PSDF funding.

KPTCL 2 2

KSEBL 1 DPR being prepared. Would

be taken up for PSDF

funding.

TANTRANSCO 2 Retendering. Would require

PSDF funding.

PED NIL NIL

PGCIL 4 (2 Nos.

Additional)

4 (SR I &

SR II is

having 2

no. Each)

SR II: one 400 KV ERS

arrived and kept at

Sriperumbudur.

SR-I received and kept at

Vizag.

765 KV ERS (one each for

SR-I and SR-II) tendering

under progress.


Chairperson, SRPC had stated that one or two ERS S/S at lower capacity/voltage level as

deliberated in the earlier Meeting may be required.

PGCIL had stated that they were examining feasibility of ERS S/S technically/ commercially.


TSTRANSCO had informed that they had floated the tender and it would be finalized shortly.

KSEBL had informed that the DPR was being prepared and they too would approach for

PSDF funding.

TANTRANSCO had informed that it was being re-tendered and they would require PSDF

funding.

NPC had informed that PSDF funding for ERS proposal for AP had been discussed in the

Appraisal Committee. Since there was less inflow into the PSDF funds, it had been decided to

prioritize the schemes. Schemes were prioritized based on national, ISTS, State importance

etc. Proposal of AP was falling in lesser priority and subject to the availability of funds, the

proposal may get considered. There was only around Rs 3,000 crores left while requisitions

were of the order of Rs 7,000 crores. Considering the paucity of funds, it may be prudent that

all states consider the ERS proposal as „Business as Usual‟.

APTRANSCO had stated that two of the ERS had been procured at their own cost and only

for 3rd

ERS, they were seeking PSDF funding. In absence of PSDF funding, it may be difficult

to take up the 3rd

ERS.


MS, SRPC had stated that the functional requirement had been communicated by MoP and the

status was being reviewed at the highest levels. It was suggested to NLDC/NPC that requests

of SR states be considered since ERS was critical and also relatively not too costly.

NPC had expressed that identified ERS requirement was irrespective of funding. However,

Monitoring Committee Meeting was scheduled on 25.08.2017 and the concerns of SR

constituents would be put forth to the Committee.

TCC had requested NPC/NLDC to favorably consider the proposal of ERS of APTRANSCO,

KSEBL, TANTRANSCO and TSTRANSCO for PSDF funding. Monitoring Committee could

also be appraised of the concerns of SR constituents.

SRPC deliberations

27.4 ED, NLDC said that he was in agreement with views of NPC stated in TCC. The ERS approvals

were kept on hold but were not denied. Fund inflow was rather limited presently and therefore

there was a need of prioritization. However, they would look into this issue.

27.5 SRPC suggested that NPC/NLDC could favorably consider the proposal of ERS of

APTRANSCO, KSEBL, TANTRANSCO and TSTRANSCO for PSDF funding since they were

part of Crisis Management Measures being monitored at highest level. Monitoring Committee

could also be please appraised of the request of SR constituents on this matter.

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

28.1 Status of implementation of Bus / Line Reactors / Dynamic Compensation approved in the

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

below:

Entity Bus Name Status REMARKS

KPTCL

Hoody Reactor erected on

platform.

October 2017

Nelamangala Reactor erected on

platform

December 2017

Entity Bus Name

Capaci

ty in

MVA

R

Approved

in Type Remarks

PGCIL

Yelahanka 2 x 63 Bus

Deferred as per 40th

SCPSPSR. When

Madhugiri line will come

it will be expedited.

Cuddapah 50 to

125 39

th SC Yet to be awarded

APTRANSCO

Vemagiri 125

36th

SC

Bus Kalpakka and Kurnool is

expected by October

2017

Vemagiri and Chittoor is

expected by December

2017.

Kurnool 125 Bus

Kalpakka 125 Bus

Chittoor 125 39th

SC

Vijayawada 125 39th

SC It was noted that a


separate reactor at

Vijayawada in scope of

AP had been identified.

The exact location could

be firmed up by

APTRANSCO.

APTRANSCO/

APGENCO

VTPS Stage

IV 125 39

th SC

APGENCO informed that

reactor enquiry was being

taken up.

It was noted that this

reactor was different from

the APTRANSCO reactor.

KPTCL

Davangere 125 39th

SC KPTCL had informed that

they had taken up with

CEA for reviewing.

During studies no reactors

had been considered in

that area and arrived at

125 MVAR requirements.

Now two reactors had

come at Guttur and

Talaguppa.

Talguppa 125 39th

SC

TANTRANSCO Almathy 125 39

th SC Tender under progress

Kayathar 125 39th

SC Tender under progress

TANTRANSCO/

TANGEDCO Mettur 125 39

th SC

Diverted from Palavadi.

Structural works are over

TSTRANSCO

Mamidipalli 125

36th

SC

Bus Gazwel: Commissioned

on 31.03.2017

For all other reactors Civil

Works are in progress.

Expected to be

commissioned in

September 2017.

Gajwel 125 Bus

Sankarapalli 125 Bus

Mehboob

Nagar 125 Bus

Malkaram 125

Bus

TSTRANSCO: Sanction of funding from PSDF is received for 5 Nos of 125 MVAR reactors

from MoP on 05.09.2016. Works for all five reactors awarded in September 2016 and works

are in progress.

TSTRANSCO/

TSGENCO

Srisailam

LB 125

39th

SC

Erection of GIS Bus

reactor is not suggestible

due to financial

implications and space

constraint in 400 kV GIS

of SLBHES. Hence, the

erection of Bus reactors

will be examined at other

end. TSGENCO was

requested to take up the

issue with Standing

Committee.

NPCIL Kaiga 2 x 125

Bus

KGS had informed that

both the reactors are

expected to be

commissioned by

December 2019. Financial


approval had been

received. They were in the

process of floating the

tender.

UPCL Udupi 2 x 125 39th

SC

KPTCL had informed that

the line is planned to be

LILOed at Drinking water

substation between UPCL

and Hassan. Subsequently

the studies would be put

up to Standing

Committee. UPCL will

submit the issues to

KPTCL and KPTCL will

discuss with PCKL to sort

out issues. UPCL had

submitted all the

information as required.


TSTRANSCO had stated that TSGENCO had already communicated about the space

constraints in providing reactor at Srisailam LB. Joint study at CEA may be required for

optimal location for reactor in lieu of Srisailam LB reactor since Srisailam LB is connected

to TSTRANSCO, PGCIL & APTRANSCO.

TSGENCO/TSTRANSCO had informed that earlier there had been a joint inspection

wherein, it was noted that that the reactor could not installed at Srisailam LB and alternative

location was to be identified/suggested.

It was noted that CEA had called for Agenda for the 41st Standing Committee on Power

System Planning. TSTRANSCO was suggested to take up this issue of space constraints at

Srisailam LB. TSTRANSCO could support any alternative/proposal through internal studies.


28.3 In the 131st Meeting of OCC,SRTS I had informed that commissioning of NGR bypass

breaker/isolator for all reactors in SRTS I had been completed except the following :

400 kV Nellore-Thiruvalam line I & II, Thiruvalam-Kurnool I & II, Kozhikode-Mysore I & II

line reactors : October 2017

28.4 Dynamic Compensation (Approved in 36th

SC)

Entity Bus Name

SC

MVA

GVA /

KA

Dynamic

Compensation

(STATCOM)

Mechanically

Switched

Compensation

(MVAR) Remarks

Reactor Capacitor

PGCIL

Hyderabad 18.4/

26.5

+ 200 MVAR 2x125 1x125

June 2019 Udumalpet 19.4/

28.0

+ 200 MVAR 2x125 1x125

Trichy 12.5/

18.0

+ 200 MVAR 2x125 1x125


28.4.1 PSDF– Installation of STATCOM by Power grid in Southern Region

The following had been noted in earlier Meeting:

PGCIL had informed that 90% PSDF funding for STATCOM was envisaged.

The following had been noted in the TCC Meeting:

PGCIL had informed that the project was awarded in March 2017 with a schedule of June

2019.

PGCIL had clarified that PSDF funding was envisaged at 80 %.


28.5 Reactive Power Planning

28.5.1 Status of Capacitor installation in Transco/Discoms is given below:

Utility Reactive Power Planning Voltage

level

Remarks

APTRANSCO

Kadapa: 288 MVAR

Vijayawada: 136.8 MVAR

Visakhapatanam:146.2

MVAR

On 33

kV side

14.4 MVAR commissioned

0 MVAR commissioned

0 MVAR commissioned

APSPDCL 802 MVAR 30 MVAR commissioned

APEPDCL 276 MVAR 0 MVAR commissioned.

KPTCL Bengaluru Tr. Zone:708.8

MVAR

12.1 kV LOA issued.

Bagalkot Tr. Zone: 258.1

MVAR

12.1 kV Material supplied. Erection

completed/under progress.

Hassan Tr. Zone: 150.8

MVAR

Material supplied. Erection

completed/under progress.

Mysore Tr. Zone: 60.9

MVAR

3x2.9 MVAR commissioned

Gulbarga Tr. Zone: 98.60

MVAR

No update

Tumkur Tr. Zone: 281.3

MVAR

12.1 kV 40.6 MVAR commissioned.

34.8 MVAR EI approval

awaited.

KSEBL

360 MVAR

66 kV Works will be taken up after

approval. 11kV TANGEDCO 34 x 2.4 MVAR 11 kV

16 x 2.4 MVAR 22 kV 14 x 2.4 commissioned

35 x 2.4 MVAR 11 kV Tender to be floated.

51 x 2.4 MVAR 22 kV Tender to be floated

13 x 24 MAVR 110 kV Tender under negotiation.

82 sets of 11 kV, 2.4 MVAR

Capacitor Banks in

Coimbatore Region

11 kV Tender to be floated.

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.

28.6 PSDF – Funding of the schemes of the state utilities for installation of capacitors in the

state network at transmission / distribution network

28.6.1 MS, Appraisal Committee & ED, NLDC vide letter dated 22.06.2016 had stated that the matter

was deliberated by the Appraisal Committee during the Meeting held on 31.05.2016 wherein, it

was decided that assessment of capacitor requirement may be carried out at regional level by

engaging expert agency like CPRI. In the 30th

Meeting, SRPC had approved TCC

recommendation that a regional proposal for capacitors installation would be put up for PSDF

funding. The Study would be conducted by CPRI. A Meeting in this regard was conducted on

29th

November 2016 (MoM available on SRPC website).

28.6.2 PSS/E Base Case model had been received from the states of SR for low voltage scenario.

Complete converged network of SR had also been modeled by SRLDC/SRPC and submitted to

CPRI on 23rd

March 2017 for capacitor requirement assessment. SRPC vide letter dated

27.03.2017 had again requested constituents to make necessary arrangements to contribute

towards Consultant Fee charges for assessment study to CPRI. SRPC vide letter dated

03.05.2017 had placed work order on CPRI for carrying out the assessment studies for Southern

region (except Karnataka) and the total cost would be Rs.17.35 lakhs, excluding taxes.


TSTRANSCO had requested NLDC/NPC to consider the two Capacitor proposals for PSDF

funding. It was noted that the report of CPRI was awaited.

MS, SRPC had informed that CPRI Report was likely to be finalized shortly.


29. OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS

29.1 In Meetings of CCM, the following had been noted:

PCKL vide letter dated 25.04.2017 had informed that KPTCL had paid Rs 73,72,176/- to

CSPDCL towards bilateral transactions between WR-SR constituents for the period from

October 2001 to November 2002.

PGCIL SR-II had informed the forum that Rs 13,38,631/- had been received from CSEB

w.r.t. payment towards 50 % of UI charges.

GUVNL vide letter dated 30.05.2017 had informed that PCKL had made a payment of Rs

9,40,320 in favour of GUVNL. GUVNL had paid Rs 4,98,019/- to KSEBL on 24.05.2017.

GUVNL vide letter dated 07.06.2017 had informed that they had paid Rs 48,355/- to

Puducherry Electricity Board on 03.06.2017.

GUVNL had also informed that they had settled all outstanding payment to SR constituents.

Pending payments between WR& SR Constituents as on 20.07.2017 are as follows:

State Receivable from Payable to

Entity Rs Entity Rs

Andhra Pradesh

/ Telangana

MPPMCL 1,21,76,270

*

MPPMCL Nil


Karnataka MPPMCL 13,27,208 GUVNL 9,40,320

Kerala MPPMCL 1,21,47,260

CSPDCL 7,05,279

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

* In the Meeting of SR-WR held on 09.11.2016 at WRPC, Mumbai, MPPMCL had informed

that it had to receive payment from APTRANSCO and the details would be shared with

APTRANSCO/SRPC Secretariat.


29.2 Payable amount by PGCIL (WRTS / SRTS) to SR Constituents (as on 20.07.2017)

State/UT Total

Amount

to be

received

in Rs

Received

as on

01.12.2014

in Rs

Paid by

SRTS II

on

01.04.2016

in Rs

Paid by

SRTS II

on

01.03.2017

in Rs

Balance to

be

received

in Rs

Andhra Pradesh

& Telangana

47,05,447 3,69,848 10,16,847 3,48,203 29,70,549

Karnataka 49,79,733 3,91,407 10,76,120 3,68,500 31,43,706

Kerala 27,58,402 2,16,811 5,96,091 2,04,122 17,41,378

Tamil Nadu 47,21,994 3,71,149 10,20,423 3,49,428 29,80,994

Puducherry 9,24,035 72,629 1,99,684 68,379 5,83,343

Total 1,80,89,611 14,21,844 39,09,165 13,38,632 1,14,19,970

SR constituents had been requested to take up pending payment issue with concerned WR

utility directly, with a copy to SRPC / WRPC Secretariat.


30. NON-AVAILING OF OCC APPROVED SHUTDOWN

30.1 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:

Entity Feb-17 Mar-17 Apr-17 May-17 June-17 July-17

Availed % with respect to the OCC approved outages

AP TRANSCO 28 39 65 48 29 46

KPTCL 56 88 100 89 90 38

KSEBL 100 NA 67 100 100 71

TANTRANSCO 46 27 56 46 62 73

TSTRANSCO 60 60 100 50 44 53

PGCIL, SR1 71 78 61 77 53 65

PGCIL, SR2 68 68 82 60 84 58

NTPC 77 57 75 100 100 100

NLC 100 NA 100 NA 100 50

NTECL NA NA NA NA NA NA


SRPC suggested the constituents to plan outages more diligently and increase coordination with

the field and project officials.

30.2 OCC approved outage procedure

30.2.1 In the OCC Meetings, the following had been noted:

In respect of SRLDC‟s Web Based Outage Coordination System (WBOCS) a provision had

been incorporated to enter non-availing till 0600 hours of the day of shutdown as

recommended in 124th

Meeting of OCC.

D-3 should be strictly followed in case of availing of OCC approved shut downs.

SRLDC had informed that after D-3 confirmation also, if any of the shutdowns which lead

to ATC/TTC curtailment is not availed on the scheduled day there would be a delay in

revision of the ATC/TTC which would depend on the information from respective entity.

31. STATUS OF PHASE I AND PHASE II OF PROTECTION AUDIT RECOMMENDATIONS

31.1 With reference to the petitions filed by KSEB (88/MP/2016) and KPTCL (135/MP/2016) for seeking

further time-extension for completing their respective Protection Audit Recommendations (PAR),

the final Order of Hon‟ble CERC disposing of petitions was issued on 15.12.2016. In this Order, the

Commission, apart from granting last-chance time-extensions to various SR-Constituents, had also

directed SRPC to monitor the status of completion of PAR regularly in PCSC meetings and submit

bi-monthly report to the Commission confirming the completion of Phase-I and Phase-II of PAR of

the Constituents of Southern Region.

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

the compliance status of various SR-Constituents as on August, 2017 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 40 ---

2 APGENCO

(Thermal) 30.07.2017 --- 75 Based on the status furnished,

timeline for complying with

the remaining pending

recommendations (3 in no.) is

30.06.2018.

APGENCO (Thermal) has

been asked to approach

Hon’ble CERC to get

required time-extension.

NPCIL 100 NA NA 100 NA NA

KPCL NA NA 100 NA 100 NA

PNMTC NA NA NA NA NA NA

KTL NA NA NA NA 100 100

MEPL NA NA NA NA NA 100

Total 53 54 68 60 61 59


3 APTRANS

CO 31.03.2017 --- 98.57 Based on the status furnished,

the lone pending

recommendation is expected

to be completed by

31.12.2017.

4 TSGENCO

(Hydel) 31.03.2017 31.03.2017 88.23 Based on the status furnished,



recommendations (4 in no.) is

31.12.2017.

5 TSGENCO

(Thermal) 31.03.2017 31.03.2017 93.33 Based on the status furnished,

the lone pending

recommendation is expected

to be completed by

15.09.2017.

6 TSTRANSC

O 31.03.2017 31.03.2017 85.23 Based on the status furnished,



recommendations (13 in no.)

is October, 2017.

7 KPTCL 31.05.2017 31.05.2017 42.25 Based on the status furnished,



recommendations (41 in no.)

is October, 2017.

8 TANGEDC

O 31.12.2017 31.12.2017 66.67 ---

9 TANTRAN

SCO 31.12.2017 31.12.2017 50 ---

10 KSEB 30.11.2016 31.12.2017 94.81 ---

11 NPCIL

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


the lone pending

recommendation is

31.12.2017.

31.3 All above SR-Constituents were requested to adhere strictly to the time-lines given in the Order for

completing their respective pending PAR. IPP‟s for whom there are pending PAR [viz., Spectrum

PGL, GMR Barge - Kakinada, Konaseema GPL, APGPCL Vijjeswaram (Stage-I & Stage-II), &

LANCO-Kondapalli PL] were also requested to complete them at the earliest.


APGENCO (Thermal) was suggested to approach Hon‟ble CERC since they had sought

extension up to June 2018.

KPTCL had complied only around 42 % which was a matter of concern. KPTCL assured that the

works would get completed by October 2017.

SRPC deliberations

APTRANSCO was complimented for the proactive steps. Other constituents were requested to

kindly expedite implementation.



32. SPARE ICT AND REACTOR PLACEMENT AND USAGE PROCEDURE

32.1 PGCIL had informed following status of spare ICTs and Reactors as agreed in earlier Meetings:

Region Equipment Location

SR ICT Madurai (would be reaching) &

Hyderabad (was being used at

Kozhikode)

Reactor Vizag & Gooty (being used at

Somanhalli)

Status of Narendra reactor

32.2 PGCIL had filed Petition No. 58/TT/2017 in the matter of „Approval for transmission tariff from

anticipated DOCO to 31.3.2019 for 1x125MVAR 400KV Bus reactor at Hassan, Trivandrum,

Narendra (New), Gooty, Khammam, Nellore (Existing), Nagarjunasagar, 400/220 kV, 1x500 MVA

transformer at Madurai Sub-station along with associated bays and equipments, Replacement of

7x 167 MVA, 400/220 kV ICTs with 2 X 500 MVA ICT at Somanhalli Sub-station (The replaced

ICT shall be maintained as a regional spare), Replacement of 1 x 50 MVAr Bus reactor with 1x125

MVAr Bus reactor at 400/220 kV Narendra Sub-station (The Replaced Bus reactor shall be

maintained as a regional spare), 1 x 63 MVAr Switchable Line reactors at Nellore Pooling Station

on each circuit of Nellore pooling station-Gooty 400 kV Quad D/C Line along with associated bays

and equipments and procurement of 01 Nos. 500 MVA, 765/400 kV Regional Spare ICTs at

Raichur and Thiruvalam under System Strengthening-XXIII in Southern Region for the 2014-19

tariff period.‟ In Para 6 of the Order for date of hearing 07.07.2017 it is stated „…………..Further,

we are not inclined to grant AFC for Assets XII and XIII, i.e. Regional Spare ICTs at Raichur and

Thiruvalam, at this stage. The petitioner is directed to submit a comprehensive list of Regional

Spare ICTs, including Bus Reactors, line reactors, etc. their gross value, year of purchase and

petition number in which tariff was granted/claimed…………‟

TCC deliberations

PGCIL had informed that two 765 kV, 500 MVA Transformers had been approved as Regional

Spares by SRPC. One had reached the site while other was on the way. Hon‟ble CERC had

sought details of spares which had been communicated. PGCIL had sought recommendations of

SRPC since these transformers were required to meet any contingency.

PGCIL was suggested to kindly furnish details of spare ICTs/Reactors along with the Standing

Committee/SRPC approvals.

TCC noted the above. It was also reiterated that the two spare 765 kV, 500 MVA Transformers

earlier approved by SRPC, were indeed essential for enhanced reliability.


32.4 Subsequently, PGCIL vide letter dated 30th

August 2017 (Annexure-XLIII) had furnished status

of Regional Spares in SR. It was informed that two nos Regional Spares of 765 kV 500 MVA

Transformers had been approved in 23rd

Meeting of SRPC. PGCIL was taking up issue with

Hon‟ble CERC that these spares are required to meet any contingency arising upon failure of any

765 kV ICT unit in SR, which could affect bulk power transfer to SR Constituents.

33. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION


33.1 Automatic Demand Management Schemes

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

been provided by all constituents by 1st

January 2011. SRLDC & SRPC Secretariat had pointed

out that automated scheme was to be in place to meet Regulatory requirements.


AMDS logic was finalized as OD >250 MW or 20 % of Schedule, whichever lower, for 15

minutes when frequency < 49.8 Hz.

SRLDC & SRPC had suggested that new set points at 49.9 Hz be adopted.

States had pointed out that corrective action was already being taken by them as could be seen

that there were minimal incidents satisfying the proposed logic. Opportunity needs to given to

Operator to take corrective action rather than go for automatic load shedding and existing set

points were reasonable. Unnecessary interruptions to loads were not advisable in the present

scenario. In time of contingency, appropriate urgent action was being taken by SLDCs.

In the 30th

Meeting, TCC had suggested that ADMS set points could be reviewed in the next

Meeting of TCC.

33.1.3 Number of incidents satisfying the existing logic and proposed logic is given in the Table

below. It was recommended to migrate to IEGC limits of 49.9 Hz:

Month

Present settings Proposed settings as per IEGC

Frequency < 49.8 Hz for 15

Min. and OD = Min DSM

limit

Frequency < 49.9 Hz for 15 Min. and OD =

Min DSM limit

No of

instances

Meeting the

freq. limit

No of

instances

applicable to

states

No of

instances

Meeting the

freq. limit

No of instances applicable to

states

AP Kar Ker TN TS

Feb-17 NIL NIL 8 0 0 0 3 0

Mar-17 NIL NIL 35 1 2 0 2 0

Apr-17 NIL NIL 67 3 0 0 19 0

May-17 NIL NIL 85 4 0 0 7 0

June-17 NIL NIL 61 11 1 0 12 1

July-17 NIL NIL 47 7 0 0 5 2

33.1.4 TCC had recommended for retaining the set points which would be reviewed in the next TCC

Meeting.


33.1.6 The following had also been noted in the OCC Meetings:

Contingency plan in respect of generation loss at pooling station level for RE.

SRLDC had pointed out that similar to existing ADMS logic (O/D), backing down of

generation during sustained U/Ds during high grid frequency may also be required.

33.2 UFR and df/dt reliefs

33.2.1 All States had implemented AUFR and df/dt schemes fully. SRPC vide letter dated 29.01.2016

had submitted status report duly certified by SRLDC and SRPC wrt implementation of SCADA


mapping of all constituents to Hon‟ble CERC in respect of Order dated 27.11.2015 of Petition

No. 60/MP/2014. 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 3559 1207 4544 116 15186

% B/A 100 100 101 103 109 113 103

SCADA monitorable MW C 1169 2353 3557 1184 3849 116 12112

% C/B 42 79 100 98 85 100 80

Average Visible

Relief in February

2017

MW E 1127 1143 2987 1052 1873 76 8184

Wrt monitorable % E/C 96 49 84 89 49 66 67

Average Visible

Relief in March

2017

MW F 1278 1343 2942 1126 2027 76 8792

Wrt monitorable % F/C 109 57 83 95 53 66 72

Average Visible

Relief in April 2017 MW G 1281 1286 2830 1057 2083 76 8618

Wrt monitorable % G/C 110 55 80 89 54 66 70

Average Visible

Relief in May 2017 MW H 1260 959 2265 1177 2007 76 7748

Wrt monitorable % H/C 108 41 64 99 52 66 63

Average Visible

Relief in June 2017 MW I 1092 878 2179 962 2034 76 7232

Wrt monitorable % I/C 93 37 61 81 53 66 59

Average Visible

Relief in July 2017 MW I 947 1152 2602 977 2184 76 7944

Wrt monitorable % I/C 81 49 73 83 57 66 65


APTRANSCO had informed that out of 25 RTUs, 13 had been commissioned and the

SCADA mapping percentage had increased to 60.3%. For balance 30%, a composite

proposal has been put up for PSDF funding.

TANTRANSCO had informed that action had been taken for the provision of MPLS/GPRS

link and for suitable RTUs at 29 SS connected for AUFR and df/dt and the time line for

completion was April 2017. Regarding monitoring of figures connected in AUFR and df/dt,

PO had been issued for procurement of transducers and the data visibility would be

improved.

TSTRANSCO had informed that 6 RTUs had been provided for Solar Generators and for 17

RTUs procurement was being taken up and it could take 4-5 months. There were 18 RTUs

for Interstate feeders and some would provide UFR and df/dt relief quantum also. With this,

they were likely to achieve 100% mapping.

33.2.3 In the OCC it had been decided that a group of Officers from SRLDC & SRPC would visit

SLDCs and examine the exact status of feeders (whether radial or grid connected, what type of


tripping provisions are enabled, including breaker position etc). As per identified feeders list

visibility at SLDC and SRLDC may also be checked. Joint validation for Karnataka & Tamil

Nadu was undertaken on 30.06.2017 & 07.07.2017. Joint validation for AP, Telangana and

Puducherry has been planned for 01.08.2017, 02.08.2017 and 13.08.2017 respectively. In the

OCC Meeting, the following had been noted:

KPTCL had stated that the steps on the observation of the joint validation would be taken to

address the issues

TANTRANSCO had stated that the issues not involving purchase pointed out in the joint

validation would be rectified within three months i.e. 15.10.2017. Other issues would be

addressed within six months. The joint validation report had been communicated to the P&C

wing for rectification.


APTRANSCO had informed that 20 RTUs out of 25 had been commissioned and they had

achieved 64 % visibility. 5 RTUs would be commissioned shortly. Balance RTUs are

covered under OPGW scheme approved for PSDF funding.

TSTRANSCO had informed that with commissioning of 16 RTUs shortly, they would

achieve 100% visibility.

Joint validation had been concluded in respect of AP, TS, KAR, TN & Puducherry and was

scheduled for Kerala during end August 2017. All constituents were suggested to kindly

initiate suitable action based on the joint validation report.


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

33.3.1 RGMO response is being analyzed in the Meetings of OCC. SLDCs were to analyze RGMO

instances posted by SRLDC for the generators in their control area and initiate suitable action as

per Order in respect of 84/MP/2015. Inadequate Response is to be taken up with SERC

(Petition No.302/MP/2013).

33.3.2 Performance of RGMO is being analyzed in the OCC forum. Summary for Southern Region

(state-wise details are given in Annexure-XLIV) is given in the Table below:

Hydro Thermal TOTAL

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

Possible

(MW)

Actual

(MW) %

26.04.2017

-78 -18 23% -965 -307 32% -1043 -325 31%

09.05.2017

32 15 47% 1041 250 24% 1073 265 25%

18.05.2017

39 114 292% 1021 333 33% 1060 447 42%

20.05.2017

40 -46 -215% 1088 276 25% 1127 229 20%

23.05.2017

24 28 117% 1127 266 24% 1151 294 26%


33.3.3 8th

Meeting of RGMO/FGMO had been convened on 04th

April 2017 (MoM available in SRPC

Website). All concerned had been requested to initiate action w.r.t the Summary /

Recommendations as listed out in the Minutes:

Numbers of units were not giving the desired performance. SLDCs would call for a meeting

of the embedded generators within 20 days and take up issues in respect of RGMO/FGMO

with MI performance and extension of RGMO status to SLDC/SRLDC. Within 30 days,

MoM (by 03.05.2017) would be communicated to SRPC/SRLDC. Inadequate response

could be taken up by SLDC‟s with respective SERC‟s in line with Orders of Hon‟ble CERC

in respect of Petition No.84/MP/2015 and 302/MP/2013.

NLC, NTPL, CEPL, IL&FS, HNPCL, TPCIL, SGPL, JSWEL & UPCL would carry out

necessary changes/modifications through their OEM‟s/Concerned Entities to ensure RGMO

compliance as mandated in IEGC. Compliance Report would be communicated within 30

days (by 03.05.2017).

Few had implemented dead band in the Operating Frequency Range. It was noted that such

dead band, if any, was to be immediately disabled and confirmation was to be

communicated by 03.05.2017.

It was noted that different logics had been implemented by different generators for RGMO

compliance. It was therefore decided (Meeting planned on 12.04.2017) to have a Sub Group

Meeting to have a better understanding of different logics. All Generators to note that this

was only for enhanced understanding. However, onus to deliver mandated RGMO/FGMO

with MI performance as per Regulations was on the concerned generator only.

Some of the generators were disabling RGMO without informing / getting concurrence from

SLDC/SRLDC. IEGC provision states „5.2(f)(ii)(c) if any of the generating units is required

to be operated without its governor in operation as specified above, the RLDC shall be

immediately advised about the reason and duration of such operation.‟ The IEGC provision

needs to be complied with.

SRLDC had informed that after 03.05.2017, performance would be analyzed and if there

was no significant improvement, they may be constrained to approach higher body in this

regard. Performance could be reviewed in the next Meeting in June 2017.

Higher resolution (second sampling or below) could be furnished for better assessment of

RMGO performance.

33.3.4 A Sub Group Meeting had been conducted on 12th

April 2017 and the logic issues had been

deliberated. SRLDC vide letter dated 12.06.2017 had communicated regarding implementation

of RGMO as per 5th

Amendment of IEGC. Salient points of deliberations in the RGMO

subcommittee Meeting held at SRPC Bangalore on 12.04.2017 were also included in the letter.

SRPC vide letter dated 15.06.2017 (Annexure-XLV) had communicated to all concerned in this

regard.

States had carried out RGMO/FGMO Meeting for intra-state generators as given below:

Constituent Date of meeting

AP SLDC 28.06.2017

KAR SLDC 23.06.2017

KER SLDC 21.04.2017


TN SLDC Being discussed in the monthly state OCC meeting

TS SLDC 18.07.2017

33.3.5 In the 5th

IEGC Amendment, following are the salient points in respect of RGMO/FGMO:

Coal/lignite based thermal generating units of 200 MW and above (earlier mentioned as

thermal)

All hydro units of 25 MW and above (earlier it was 10 MW and above)

Open Cycle Gas Turbine/Combined Cycle generating stations having gas turbines of capacity

more than 50 MW each: with effect from 01.10.2017 ( earlier it was exempted)

Periodic checkups by third party should be conducted at regular interval once in two years

through independent agencies selected by RLDCs or SLDCs as the case may be. Cost of such

tests shall be recovered by the RLDCs or SLDCs from the Generators. If deemed necessary

by RLDCs/SLDCs, the test may be conducted more than once in two years.

33.3.6 Chief (Engg), CERC vide letter dated 05.06.2017 (Annexure-XLVI) had informed the

following regarding RGMO/FGMO compliance by generators in the Region:

Central Electricity Regulatory Commission (IEGC) Regulation, 2010 at 5.2(i) provides

that generators should provide RGMO/FGMO response. Further, vide 5th

Amendment to

IEGC dated 12.4.2017, it has been provided at Regulation 5.2(h) that 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 and that the generation station shall not resort to Valve Wide Open operation of

units so that primary response is ensured.

RPC Secretariats and respective RLDCs are requested to obtain the status of availability

of RGMO/FGMO response from the generators (ISGS as well as intra-state generators)

in its region. The status of actual response being provided by generators under the

primary response may also be provided.

33.3.7 SRPC/SRLDC had furnished the Report to Chief (Engg), CERC vide letter dated 24th

July 2017

Subsequently, a list of units with inadequate performance was also furnished vide letter dated

28.07.2017 (Annexure-XLVII).

33.3.8 There were some instances of RGMO disabling whenever units were being given Technical

Minimum Schedule of 55%. In the 133rd

Meeting of OCC (13.07.2017), generators had been

advised to keep the RGMO enabled at all levels of schedules. Status point extension to

SLDC/SRLDC needs to be expedited wherever pending.


SRLDC had informed that Hon‟ble CERC had brought out Order dated 31st July 2017 in

respect of Petition No 84/MP/2015 and the following had been directed:

(a) Considering the fact that further measures have been put in place to facilitate desirable

primary response, the Commission, starting from the month of September, 2017 shall be

closely watching the primary response of ISGSs as reported by POSOCO/NLDCs. At the

State level, SLDCs shall report the frequency response of intra-State generators to the

concerned SERCs.

(b) NLDCs and SLDCs through the assistance of POSOCO shall start the process of

selecting independent third parties capable of undertaking periodic checkups to monitor


the RGMO/FGMO response. To start with selected independent third parties shall be

sent to the generating stations which are not providing the desired RGMO/FGMO

response. Independent Third Parties shall ensure that the generator has not, in any way,

prevented/disabled the governor from providing the desired response. In case, even after

enabling the governors, units are not able to provide the desired response as per the

provisions of the Grid Code, third parties, based on the submissions of the generators,

shall bring out the technical constraints, if any, which limit the primary response of the

units.

(c) All ISGSs are directed to provide primary response compulsorily in terms of Regulation

5.2 (f), (g), (h) and (i) of the Grid Code failing which we would not hesitate in initiating

action under Section 142 of Electricity Act, 2003 for not providing desired RGMO/FGMO

response without any valid reasons.

TCC had urged generators to initiate necessary action for complying with various CERC

orders; recommendations finalized in the Special/OCC meetings, CERC directives etc.

SLDCs were also requested to kindly take proactive initiative in this regard.


33.4 Demand Estimation for Operational Purpose (Clause 5.3 of IEGC)

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

demand for daily operational purpose for each 15 minutes block by 01.01.2011. In this regard,

following may kindly be noted as contained in Order dated 19th

December 2013 of Hon‟ble

CERC in respect of Petition No. 249/250/251/MP/2012:

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

forecast their demand and make adequate arrangements to avoid dependence on Unscheduled

Interchange for Meeting their demand or for injecting short term surplus power, irrespective

of the frequency.”

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

The forecast was required for RRAS and Renewable Framework also.

33.4.2 The following had been noted in earlier Meetings:

TANTRANSCO had informed that forecast of NIWE and Wind Developers was having a

difference of 600 - 700 MW (equivalent to 3 thermal units). Demand estimation was quite

accurate and they were in the process of procuring the software and they would be fully

equipped before next summer.

It was agreed that a small group would be formed at SRLDC, and demand forecast

exercise would be undertaken for individual states in coordination with SLDCs. SRLDC

was entering into MoU with IMD and weather data would be integrated.

SRLDC had informed that a Pilot Project for RE forecasting had been started. Pilot Project

for load forecasting was yet to commence. RE Connect had been entrusted the work.

Parallely, all state entities agreed that CEA could carry out state-specific forecasting.

SLDC would submit necessary data to CEA. This would not involve any financial

commitment for the states. DFID UK collaboration was being implemented by KPMG

with CEA. Telangana State has been selected for Pilot project in load forecasting and

short term power procurement optimization program.

33.4.3 TSTRANSCO vide letter dated 13th

July 2017 has nominated the Nodal Officer to facilitate

smooth interaction and data exchange between Telangana and CEA / KPMG for developing a


module „Power Procurement Cost Application‟ under work package „Renewable Energy

Deployment & Grid Integration‟.

33.5 Web Portal on Weather information for Power Sector

33.5.1 CEO, POSOCO vide letter dated 07.06.2017 (Annexure-XLVIII) had informed that an MOU

was signed between POSOCO & IMD to have an effective weather information interface,

exclusively for Power system operation. In pursuance to this MOU, dedicated web portals for all

the 5 regions have been developed jointly by IMD & POSOCO. These web portals contain

information relating to weather forecast, real time & past data related to various locations in all

the regions. The weather locations presently available with IMD in all the regions have been

mapped with the electrical locations / stations. With better understanding of this data, various

utilities in the concerned region can equip themselves with better preparedness and improved

operational planning, thereby enhancing reliability of power system operation.

33.5.2 An IMD workshop had been organized by SRLDC on 12th

July 2017 with good participation

from most of the entities.


33.6 Sudden Change in Demand/Frequency Excursion

33.6.1 In earlier Meetings, violation of Clause 5.2 (j) of the IEGC Regulations had been highlighted.

No user is to cause sudden variation in its load by more than 100 MW without prior intimation

to and consent of the RLDC. Similarly no user should reduce the generating unit output by more

than 100 MW without prior intimation to and consent of the RLDC. Necessary action is sought

in respect of demand and generation management as well as power purchases, so that clause 5.2

(j) of IEGC Regulations is not violated.

33.6.2 In the OCC Meetings, the following had been noted:

SRLDC had expressed concern that from March 2017 onwards, SR demand pattern was

experiencing sudden and abrupt load change over in the evening peak hours. SRLDC vide

letters dated 24.05.2017(Annexure-XLIX) had again taken up the issue with AP/TS/KAR

and had submitted that sharp demand changes have wide impact on governor response and

parameters of generating units, grid frequency, line flows & voltages etc. Large set point

changes in HVDC Bi pole is also resorted to which has a cumulative impact on the life of the

converter transformer. Such large quantum of load throws off during change over causes

severe over voltages in the grid. The list of lines tripped/hand tripped due to over voltage

since 1

st May 2017 during change over period was also enclosed.

SRPC and SRLDC had suggested that SLDCs may conduct a Meeting with DISCOMs and

discuss and arrive at an effective load staggering pattern which would smoothen the

changeover. Load Despatch Control Room Officials may also be sensitized to mitigate the

deviations through optimum scheduling.

APTRANSCO had informed that they had conducted a Meeting with DISCOMs and actions

to be taken were finalized and initiated. But still the issue prevailed and on 30.05.2017 at

Director Level discussions were carried out and action to be taken had been communicated to

all the concerned.


KPTCL had informed that few changes in the load changeover have been made by Discoms

in consultation with the SLDC. The changeover had improved and they were following up

the issue.


SRLDC had informed that the load changeover phenomenon still persisted in AP and

further staggering was required. Congestion warning messages had been received from

NLDC specifically during the overdrawal.

APTRANSCO had informed that staggering had been undertaken but further staggering

was planned. Half an hour district-wise shift has been planned and was being implemented

district-wise in a phased manner. About 300-400 MW of shift has already been

implemented in last 4-5 days. There was about 1,000 MW changeover in their system.

KPTCL had informed that the load staggering had been carried out in Gulbarga and

Mysore areas. SRLDC confirmed that the situation had improved in respect of Karnataka.

SRPC deliberations

33.6.4 MS, SRPC stated that it may kindly be ensured that ESCOM wise load staggering is

implemented.

33.6.5 SRPC noted the above

33.7 Arranging of interruptible loads in four groups

33.7.1 As per IEGC, to maintain the frequency within stipulated band and also to ensure network

security, interruptible loads are to be arranged in four groups of loads. This was for the purpose

of scheduled power cuts/load shedding, loads for unscheduled load shedding, loads to be shed

through UF relays, df/dt relays and loads to be shed under any SPS Scheme. These loads are to

be grouped in such a manner that there was no overlapping between different groups of loads.

33.7.2 Existing schemes were not Meeting Regulatory requirement fully and further action was

required in this regard. Constituents had been requested to ensure necessary compliance.

33.7.3 SRPC suggested action for necessary compliance.

33.8 PSS Tuning

33.8.1 5th

Meeting of PSS tuning was conducted on 26th

July 2017 and MoM is available at SRPC

website. PSS Study group had analyzed the Step Response Test Reports for the generators

which had furnished the reports and recommendations had been finalized. It was kindly

requested that necessary action may be taken as finalized in the PSS Meetings. SRT of

following units had been analyzed in the PSS Meetings and necessary action had to be taken as

per Recommendations:

Entity Generating Stations/Units

APGENCO Rayalaseema TPS U1 to U5; VTPS U1 to U4 & U7; SDSPP U1&U2;

Srisailam RB HEP U1 to U7; Lower Sileru HEP U1 AP IPP HNPCL U1 & U2 TSGENCO Nagarjunasagar HEP U1 to U8; Srisailam LB HEP U1 to U6; Kakatiya TPS

U1 & U2; Kothagudem TPS U10 & U11; Singareni Collieries

(Information on reports to be clarified) 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; Sharavathy HEP U1,2,3,4,5,6,7,9 & 10


KAR IPPs UPCL U1 & U2; JSWEL U1 to U3 KSEBL TANGEDCO MTPS-I U1 to U4; NCTPS St-I U1 to U3; Tuticorin TPS U2 to U5; NCTPS

St-II U1; Kadamparai HEP U1 & U2, Mettur-II U1. TN IPPs CGS NTPC- Ramagundam U7; 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; NPCIL-KKNPP U1;NLC-Neyveli

TPS II Exp. U1 & U2; (NLC & TN JV) NTPL U1; NTPC-Kudgi U1 ISTS connected IPPs TPCIL U1; Coastal Energen U2; IL & FS U1 & U2

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

Entity Generating Stations/Units

APGENCO VTPS U5 & U6; Lower Sileru HEP U2 to U4 AP IPPs TSGENCO Kothagudem TPS U7 & U8 KPCL Raichur TPS U4; Yeramarus TPP; Sharavathy HEP U8 KAR IPPs JSWEL U4 KSEBL Idukki HEP U1 to U6 TANGEDCO NCTPS St-II U2; Tuticorin TPS U1; Kadamparai HEP U3 & U4 TN IPPs STCMS CGS NTPC-Ramagundam U1 to U6; NTPC-Kudgi U2; NLC-Neyveli TPS I Exp.

U1 & U2 (SRT reports not submitted); NPCIL- KGS U1 to U4; NPCIL-

MAPS U1 & U2; NPCIL-KKNPP U2 ISTS connected IPPs TPCIL U2; Coastal Energen U1; Lanco Stage II & III; SGPL-Nellore

33.8.2 In the 6th

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

website), it had been decided that a small group comprising of representative of Protection Sub-

Committee of respective RPCs and NLDC, NTPC would be formed to finalize a common

procedure.

33.8.3 SRPC urged generators to initiate necessary action on the recommendations finalized in the PSS

Meetings.

33.9 Energy Generation data Management from Renewable Energy Sources

Monthly generation data in respect of renewal energy sources is to be submitted to CEA with a

copy to SRPC.

33.10 RSD & Technical Minimum

33.10.1 Hon „ble CERC had approved the detailed procedure for taking unit(s) under Reserve Shut

Down and Mechanism for Compensation for Degradation of Heat Rate, Aux Compensation

and Secondary Fuel Consumption, due to Part Load Operation and Multiple Start/Stop of Units

which had come in effect from 15.05.2017. This mechanism had come in effect at an apt time

and was likely to be effective during instances of falling demand and high RE injection.

33.10.2 NLC had expressed certain concern that there was considerable loss of generation in the recent

past, since URS Power was not available for sale. NLC had requested that from URS Power

available, some quantum could be kept aside as a comfort level to take care of


contingencies/operational flexibility, while balance URS could be surrendered to generators

for trade. NLC vide letter dated 22.05.2017 (Annexure-L) had raised Technical problems in

implementing IEGC fifth Amendment and issues of URS sale. Subsequently SRPC vide letter

dated 26.05.2017 (Annexure-LI) had taken up the issue with the States. It could be seen that

against a surrender of about 152 MU, consent had been given for only about 48 MU.

TANTRANSCO vide letter dated 21.06.2017 (Annexure-LII) had submitted that during the

period from 01.06.17 to 12.06.17, even though TANGEDCO has offered 72 MU for trade,

only 25 % has been traded which was not beneficial to both TANGEDCO and NLC. Hence, it

was kindly requested that necessary arrangements may please be made at NLC end to increase

the quantum of trade for the benefit of both TANGEDCO and NLC.

33.10.3 NTPC had filed a Petition No. 130/MP/2017 in the matter of, „Petition under Section 79 of

the Electricity Act, 2003 read with Part 7, Clause 4 of the Central Electricity Regulatory

Commission (Indian Electricity Grid Code) Regulations 2010 in regard to difficulties faced

in implementation of the Mechanism for compensation for degradation of Heat rate,

Auxiliary Power Consumption and Secondary Fuel Consumption due to Part Load Operation

'and Multiple Start/ Stops of Units.‟ In the ROP (for date of hearing 20.07.2017) Hon‟ble

Commission had directed to issue notice to the Respondents on admissibility of the Petition.

The Petition was to be listed for hearing on 21.9.2017 on admissibility.

33.10.4 NLC had filed Petition No. 144/MP/2017 in the matter of, „Petition under CERC (IEGC)

(Fourth Amendment) Regulations 2016 and CERC's DOP on Reserve Shutdown and

Compensation Mechanism dated 5.5.2017 for seeking upward revision of the Technical

Minimum fixed for schedule of operation of NLCIL lignite based Generating Stations (TPS I

Expn, TPS II stage 1 & 2, TPS II Expn) and other related issues.‟ In the ROP (for date of

hearing 27.07.2017) Hon‟ble Commission had admitted the petition and directed to issue

notice to the Respondents on admissibility of the Petition. The Petition was to be listed for

hearing on 14.9.2017.


NLC had requested for consent of beneficiaries for URS sale to the extent possible. In

case of TN, they were getting consent of 60-70% of which 50% was being traded by NLC.

In last 10 days, they were able to trade 70% of the consented quantum.

TSTRANSCO had informed that any surplus beyond the spinning reserve was being

released for URS sale. However many of the times, NLC was not able to trade the power.

Sometimes it was leading to planning problem since exact details of sale were not being

communicated and there were issues of trade for a few intermittent blocks. Spinning

reserve was being maintained in the units having higher variable cost.

SRPC deliberations

33.10.6 Director (P), NLC thanked TANGEDCO for continuous consent for trade. Consent for 80% of

URS was given and Rs 3.5 Crore benefit had been shared with them at the rate of 16p/kwh for


this financial year. Telangana was giving consent up to first week of June which had been

stopped now though power is being surrendered. He requested AP & TS to also give consent to

NLC for URS trade so that the benefits could be shared.

33.10.7 CMD, TSTRANSCO stated that up to June 2017 consent was being given, since then they were

having deficit and spinning reserve was to be maintained. As against 1,000 MW from

Chhattisgarh they were getting only 600 MW.

33.10.8 APTRANSCO stated that since they had lot of renewable, surrender in advance was difficult.

33.10.9 All the states were kindly requested to maximize the consent.

33.11 Other Issues requiring kind attention of TCC / SRPC

Following issues which were being followed up in the Meetings of Sub-Committees of SRPC

also merit kind attention:

For 2nd

stage, UVR at Somanahalli, Nelamangala and Hoody, the issue was being followed up

by KAR SLDC with BESCOM. It had been suggested that in case BESCOM was not able to

identify the feeders, feeders at higher voltage level may be identified to trip through SCADA.

KPTCL had stated that the 2nd

stage of UVR was not required since grid voltage had

improved. Voltages had further improved with the commissioning of Tumkur-Bidadi and

Kudgi-Tumkur lines.

SRLDC had reiterated that the 2nd

stage of UVR was required. SRPC observed that as a

common philosophy two stages of UVR has been provided by KSEBL and TANTRANSCO,

therefore, KPTCL also needs to implement both the stages.

Unit-III at NTECL, Vallur (500 MW) was out from 0610 hrs on 04.06.2017 due to a fire

accident.

Scheduling of Simhadri Stage-I had been commenced by SRLDC from 01.05.2017 onwards.

Insulator replacement of Vallur-NCTPS & NCTPS evacuation lines to be expedited by

TANTRANSCO. There were instances of tripping of NCTPS Stage 2 Unit on account of

tripping of all the six evacuation lines emanating from the station.

TANTRANSCO informed that insulator replacement works had been completed.

Regarding scheduling of NTPC Ramagundam Solar Power Plant (10 MW), NTPC had

informed that written communication in this regard to MoP would be shared with

SRLDC/SRPC.

NTPC informed that the representation is under consideration of MoP.

Regarding Condenser mode of operation of NagarjunaSagar and Srisailam LB, the following

issues had been deliberated in the Special Meeting held on 28.04.2017 at Hyderabad:

TSGENCO informed that issues with Nagarjunasagar units would be rectified during

next overhaul planned during this year.

TSGENCO informed that Srisailam units were having technical difficulty. Due to space

limitations, being an underground power house, it could take around 3-4 hours to put all

machines in condenser mode of operation. TSSLDC confirmed that units are being put

in condenser mode as per grid requirement.


A Special Meeting had been convened on 04.04.2017 to discuss on the MVAR

absorption/injection. The Minutes of the Meeting are available at SRPC Website. Summary /

Recommendations of the Special Meeting are given below:

For some generators, it was noted that there was injection / absorption at the same

voltage levels though tap position and Vref were reportedly unchanged. All the

generators were requested to kindly analyze the response and take steps to

improve the performance.

It was noted that there were still some margins available as per Capability Curve and

generators could consider improving the MVAR interchange.

It was noted that few units were not keeping the Vref at nominal and were changing it

manually to control / restrict the MVAR interchange. This was to be discontinued

immediately.

SLDCs would discuss MVAR issues for embedded generators along with

RGMO/FGMO issues.

SRLDC would take up the status point availability to SRLDC of the GT taps for ISG

stations wherever not extended.

MVAR testing would be taken up for a few stations shortly and schedule would be

communicated by SRLDC.

NTPL Unit I & II units were observed to be injecting MVAR up to 420 kV. As per Capability

Curve the limit is 180 MVAR absorption at full load (500 MW). NTPL had informed that Tap

position had been changed at Unit I and AUT tap position change will be carried out before

the unit is back on bar. For Unit II it would be taken up during next shut down.

MVAR testing of BTPS (KPCL), Singareni(TS), NTPL, TPCIL & SGPL was planned.

Mock Tests for SPS of Major Inter Regional links & KKNPP Units had been carried out as

per the following schedule and Reports issued:

23.03.2017 for HVDC Talcher– Kolar links

24.03.2017 for 765kV Raichur-Solapur lines

28.03.207 for Kudankulam Units-1&2.

All concerned states/PGCIL were requested to take action to rectify issues as mentioned in the

Reports which are already forwarded to all.

System Protection using Optimization Technique (SPOT) Engine was discussed in earlier

OCC Meetings. A Meeting of SRLDC, SR II with ABB and Kolar was held on 03.03.2017. In

the 131st

Meeting ABB had made a presentation on the same.

N-1 violation of Trichy, Madurai, Guttur, Hoody, Gazuwaka, Nellore, Nelamangala, Pugalur,

Kozhikode & Narendra ICTs were noted. High loading on 400 kV Vemagiri PG- Vijayawada,

Vemagiri PG - Gazuwaka, Mettur – Karamadai, Kolar-Hoody, NPS-Nellore, Gooty –

Nelamangala & Gooty - Somanahalli lines were observed. System strengthening beyond

Vemagiri PG Station was to be expedited.

APTRANSCO had expressed concern that higher injection at Gazuwaka and Vemagiri (PG)

by PGCIL / POSOCO was stressing their system.

Upper Sileru - Balimela line had been idle charged from 8th

January 2015 from Upper Sileru

end.


KSEBL had requested for charging Kuzhithurai- Parassala (KZ- PR) feeder, which was closed

by TANTRANSCO.

KSEBL had pointed out that Konaje-Manjeswaram 110 kV feeder had tripped on earth fault on

09.05.2017 night and was restored on next day evening only. Two substations in Kerala were

out during the period, resulting in public uproar. KSEBL had requested KPTCL to kindly look

into the issue to attend the breakdown works on this feeder within minimum possible time.

KSEBL had offered that manpower for patrolling and carrying out work can be shared by them

if required. KPTCL had agreed to look into the matter.

TSTRANSCO had appraised about the constraints in revising STOA on daily basis to suit

state‟s Load Generation balance requirements. If a request for revision/curtailment is

submitted by giving two days‟ notice, till SRLDC gives its approval TSTRANSCO is not able

to do the next revision. SRLDC had submitted the following:

SRLDC has been approving all the requests for revisions (received before 17:30 Hrs) on

the next day itself generally by 16:00 hours. In case any difficulty was faced by any

applicant, e-mail requests are also being processed.

Validation is incorporated to attend the revisions without any miss.

In case the applicant not able to submit revision request even after 1600 hrs of a day due

to pending approval of earlier request, the constraint to be informed to SRLDC through e-

mail/telephonically.

Applicants who are defaulters in STOA charges payment are blocked (with prior

intimation) from accessing the STOA web-portal.

Telangana may also ensure that their traders submit the revision request before 17:30 hrs

and paid all the dues.

KSEBL had informed that on 29.04.2017 market split was imposed for import to S3 control

area for the blocks from 77 to 89. KSEBL vide letter dated 29.04.2017/05.05.2017 had taken

up the issue with NLDC. IEX vide letter dated 10.05.2017 had clarified that based on IEX

requisition corridor was made available to IEX by NLDC through exception file. SRLDC had

furnished that against a margin of 440 MW (2851-581(LTA) – 322(MTOA) – 204.18(STOA)),

Bid of Kerala was 455.45 MW (more by 15.45 MW).

All regional entities had been requested to furnish the details regarding the quantum and

specifications of spare SEMs and DCDs. It was suggested that all Regional Entities may keep

certain percentage of SEMs and DCDs which may help in contingencies and emergency

requirements. Number of times it was observed that procuring and installing takes a long time.

NTECL Vallur vide E-Mail dated 15.03.2017 had requested SRLDC to send the information

regarding triggering of RRAS message during triggering of RRAS event. SRLDC informed

that they would be forwarding the NLDC message but quantum may vary as per SRLDC

scheduling program.

SRLDC vide E-Mail dated 27.03.2017 had expressed concern on the delay in adhering to

SRLDC instructions by PGCIL in emergency conditions. The flow on 400 kV Nellore PS-

Nellore D/C line was more than 1100 MW each continuously on 27.03.2017. Since the

situation was emergency, SRLDC had given code to close 765 kV Kurnool-Nellore PS line-

1(at 11:53 hours), which was under open condition on High voltage. But the line was not

closed till 15:23 Hrs by SRTS-1, PGCIL. SR I, PGCIL had clarified that without removal of

foreign material, the line can‟t be charged as it may not hold. Hence under intimation to


SRLDC, SR I had taken up the work of removal of foreign material and then charged the line

at 15:23 hours.

High voltages issues in AP & Telangana had been raised in the OCCM. This is causing

tripping of 400 kV lines on Overvoltage and forcing the lines to be kept open on high voltage

for long duration as a regular phenomenon. It had affected wind evacuation also. The

following was suggested

Expediting Reactor commissioning

MVAR absorption by the Conventional and RE generators

Staggering of over voltage trip settings in all the transmission lines as advised by

SRPC

It was noted that there may be some regulatory provisions which could prevent MVAR

absorption by the RE generators. APTRANSCO was requested to look into the issue.

In addition, HVRT set points and the taps positions of the wind generators could also

be ascertained / optimized.

KSEBL had filed a Petition No. 93/MP/2017 „Petition under Section 79(1)(a), 79(1)(b),

79(1)(f) of the Electricity Act, 2003 and Regulation 30 of the CERC(Terms and Conditions of

Tariff) Regulations, 2014 seeking clarification on payment of “Other Charges‟ claimed by

NTPC and Maithon Power Ltd. in the monthly energy bills of the generating stations and the

claim of higher Annual Fixed Cost‟ for the tariff period 2014-19, over and above the Annual

Fixed Cost approved by the Commission in the tariff orders‟. In the ROP (for date of hearing

06.07.2017), the Commission directed the petitioner to serve copy of the petition on the

respondents immediately. The respondents were directed to file their replies by 31.7.2017,

with an advance copy to the petitioner, who may file its rejoinder, if any, by 18.8.2017. The

Commission directed the parties that due date of filing the replies and rejoinder should be

strictly complied with. No extension shall be granted on that account.

APTRANSCO had filed a Petition No. 237/TT/2016 „Determination of tariff of the inter-State

transmission lines connecting two states for the APTRANSCO owned transmission line/system

as per the Central Electricity Regulatory Commission‟s order dated 14.3.2012 in Petition No.

15/SM/2012 in accordance with Central Electricity Regulatory Commission (Terms and

Conditions of Tariff) Regulations, 2014‟. In the RoP (for date of hearing 20.06.2017) the

Commission had directed „……..Taking into consideration the submissions of APTRANSCO

and TCTL, the Commission directed Chief (Engineering), CERC to convene a meeting of

technical teams of APTRANSCO and TCTL along with the representatives of SRPC regarding

the utilization and sharing of the transmission charges of the instant transmission lines and

submit a report to the Commission within 45 days.‟ Subsequently a meeting was convened on

11.07.2017 by Chief (Engineering), CERC.

PGCIL had filed a Petition No. 214/TT/2016 in the matter of „Determination of transmission

tariff for 2 nos. 400 kV bays each at Nagapattinam pooling station and Salem New

(Dharmapuri) for terminating Nagapattinam PS - Salem New (Dharmapuri) 765 KV D/C Line

(Initially charged at 400 KV) being implemented under tariff based bidding and 1 no. 63

MVAR line reactor at Nagapattinam PS and Salem New (Dharmapuri) each for both circuits

of Nagapattinam PS -Salem New (Dharmapuri) 765 KV D/C Line (Initially charged at 400

KV) under "Common Transmission scheme associated with ISGS projects in

Nagapattinam/Cuddalore area of Tamil Nadu - Part-A1 (b)" in Southern Region under CERC

(Terms and Conditions of Tariff) Regulations, 2014‟. In the RoP (for date of hearing

20.06.2017) the Commission had directed „……..the respondents to file their replies by


16.8.2017 with an advance copy to the petitioner, who shall file its rejoinder, if any, by

25.8.2017 failing which the matter would be decided on the basis of the information already

available on record. Subject to the above, the Commission reserved the order in the matter.‟

PGCIL had filed a Review Petition No. 61/RP/2016 in Petition No. 127/TT/2014 in the matter

of „Review petition under Section 94(1)(f) of the EA, 2003 read with Regulation 103(1) of the

CERC (Conduct of Business) Regulations, 1999, seeking review of order dated 29.7.2016 in

Petition No. 127/TT/2014‟ . In the Order dated 29.06.2017 the Commission had stated

„……..9. The Commission has also taken a similar view in order dated 27.6.2016 in Petition

No. 236/MP/2015. The relevant portion of the order is extracted hereunder:- “42.

…………..(a) It is noted that the petitioner completed its entire scope of the work on

27.3.2015. However, due to non-availability of inter-connection facility required to be

developed by NTPC and PGCIL at each end, it could not commission the transmission line.

Therefore, the transmission charges for the period from 4.8.2015 to 23.8.2015 shall be shared

by both NTPC and PGCIL in the ratio of 50:50.…..” 10. In the light of the above discussion,

we do not find any merit in the contention of the petitioner that there is no mechanism for

recovery of the transmission charges of the instant assets and accordingly, the review of the

impugned order stand on the ground is rejected.‟

TPCIL had filed a Petition No.193/MP/2016 in the matter of „Petition under Regulation

6.5(17) of the CERC (Indian Electricity Grid Code) Regulations, 2010 (Grid Code) read with

Regulation 111 of the CERC (Conduct of Business) Regulations, 1999 seeking a direction to

the respondents to act pursuant to the Grid Code and carry out consequential steps post

declaration of Grid Disturbance‟. In the ROP (for date of hearing 25.04.2017) the

Commission had reserved the order in the petition.

Hon‟ble Commission in Petition No. 07/SM/2017 in the matter of „Determination of tariff of

the inter-State transmission lines connecting two states‟. In the Order dated 12.05.2017, the

Commission had passed the Order „………In view of the above, State utilities whose lines

have been certified by respective RPCs to be considered under PoC should also file the tariff

petition under the 2014 Tariff Regulations.‟ The lines of TANTRANSCO, KSEBL & KPTCL

are covered in the Order.

In Petition No 12/SM/2017, „Operationalization of LTA of Long Term Transmission

Customers (LTTCs) as per Regulations 8(5) of the CERC (Sharing of inter-State Transmission

Charges and Losses) Regulations, 2010.‟ In the Order dated 19.07.2017 the Commission had

stated „………It is noted that CTU has not complied with the above directions. Accordingly,

CTU is directed to show cause, latest by 4.8.2017 as to why action under Section 142 of the

Electricity Act, 2003 should not be initiated against it for non-compliance of Commission‟s

directions dated 15.10.2015 and 28.9.2016 and the provisions of Regulation 8 (5) of the

Sharing Regulations. CTU is directed to place on record, latest by 25.7.2017, details of

generating stations where LTA has been granted by CTU subject to commissioning of several

transmission systems and only some of the transmission systems have been commissioned.

However, LTA corresponding to the transmission system commissioned has not been

operationalized by CTU.‟ The petition shall be listed for hearing on 22.8.2017.

Information regarding Cyber Security to be furnished to Chief Engineer, DPD, CEA, New

Delhi. Report on Physical Security, other Mock Drills for CMP, Mock Drill for Black Start

Restoration to be furnished to Chief Engineer, DMLF, CEA, New Delhi. Copy of the report

is to be sent to SRPC Secretariat by e-mail.


SRLDC & SRPC had stated that Point to Point Black Start mock exercise needs to be given

more importance and completed twice a year.

SRPC suggested that entities initiate necessary action to comply with the above issues.

34. IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT

SYSTEM (PMS) FOR SOUTHERN REGION

34.1 In pursuance of the recommendations of Task Force on Power System Analysis under Contingencies

constituted in the aftermath of Grid Disturbances in July, 2012, SRPC in their 26th

meeting held on

20th

December, 2014 at Visakhapatnam, had approved a proposal to procure Protection Suite

(Protection Management System - PMS) that comprises Web-based Management Software and

Protection Setting Calculation Tool through PSDF funding.

34.2 Subsequently, steps had been taken to get the scheme approved from PSDF, and Sanction Order in

this regard had been received vide MoP letter no: 10/1/2014-OM dated 02.01.2017. After the

technical & financial evaluation by BEC, Letter of Award (LoA) was placed on the successful

bidder, M/s PRDC Pvt. Ltd., on 9th

August, 2017.

34.3 Execution period for the Project is about 18 months from the date of placement of LoA (also called

“Effective Date”), and is followed by an Extended Technical Services period of 5 years. The project

execution would be monitored in terms of achieving the following milestones:

Sl. No.

Description of Milestone

Time-line for

Achieving the

Milestone (in

months from Date of

placement of LoA)

1 Placement of Letter of Award (LoA) – Effective Date 0

2 Submission of High level Design Document for

implementation of web based protection management system

& protection setting calculation tool for Southern Region to

SRPC.

1

3 Delivery of 35 No of base license of protection calculation

engine along with laptops

2

4 Delivery of associated servers, Installation and deployment

of application and database software along with standard

operating System

2

5 Delivery of web based database management system software 2

6 Building the entire southern region Network Data for

operational load flow and fault calculation

3

7 Completion of Training program on the desktop based

protection setting calculation software.

4

8 Site Acceptance Test (SAT) with one pilot state system 6

9 Real time interactive hardware and software at selected 400

kV substation at central location for fault analysis and

reporting

9


10 Building the entire southern region protection database and

substation SLD preparation for protection study

16

11 Uploading all SR-Constituents Data along with SLDs and Go-

Live

18

12 Extended Technical Services Additional 5 years

34.4 While the exact details as to how the project execution would proceed would be made known after

the submission of high-level design document by the Executing Agency, it can be broadly taken as

involving the following model work-flow:

“Protection data collection from all 220 kV & above substations and generating stations (all

protection equipment data and all relay settings data) by undertaking field visit of respective

stations Validation of the data thus collected Deployment of web-based data management

system Building up network model for operational load flow and fault calculation Building up

protection settings database Preparation of protection SLD‟s Uploading all SR-Constituents

Data along with SLDs and Go-Live” [It may be noted that some of the works may proceed

simultaneously].

34.5 Since the above activities would be taken up STATE by STATE for all 220 kV & above substations/

generating stations in SR-Grid, it may be kindly mentioned here that successful execution of the

project is critically dependent on the close co-ordination between all Power Utilities in that particular

State and Executing Agency and SRPC. For this purpose, a Nodal Officers Group for each State

comprising representatives of power utilities in that particular state will be constituted, and will be

tasked with the responsibility of (i) coordinating between [the Executing Agency, SRLDC and

SRPC], and [Personnel of the substations/ generating stations falling under their control], (ii)

arranging for submission of required data from the concerned substations/ generating stations as per

the formats proposed by the Executing Agency, (iii) arranging permissions for entry into concerned

substations/ generating stations, and access to all protection relays & equipment & bays for

extraction/ collection of relay settings/ equipment data details.

34.6 There would be a kick-off Meeting with all above Nodal Officers (of all States) at SRPC Secretariat,

Bengaluru in which the modus operandi of project execution will be detailed by the Executing

Agency. After commencement of the project, there would be monthly review meetings [which will

be held alongside monthly held Protection Coordination Sub-Committee (PCSC) meetings] during

which the concerned Nodal Officers will have to participate and take steps to sort out the pending

issues relating to substations/ generating stations falling under their control.


LOA has been placed on M/s PRDC and Go-Live was scheduled for 18 months after LOA.

Kick off Meeting would be convened shortly.

TCC requested entities to extend all necessary support to complete the project as per schedule.


34.9 MS, SRPC thanked Shri G Kumar Naik, MD, KPCL whose vision and guiding factor during his

tenure as Chairperson, SRPC had helped initiate the scheme.


35. POWER SYSTEM ANALYSIS GROUP (PSAG-18) MEETING HELD ON 4TH

JULY, 2076 AT

400/ 220/ 66 KV HOODY SUBSTATION OF KPTCL IN THE CONTEXT OF FREQUENT

TRIPPING OF 400/ 220 KV ICT‟S

35.1 In the past few months, frequent tripping of 400/ 2220 kV ICT‟s had been observed at Hoody SS

with a concomitant load loss of about 500 – 750 MW in every tripping. During their discussion in

regular monthly held Protection Coordination Sub-Committee (PCSC) meetings, the following

issues concerning Hoody SS had been noticed, which required urgent action by KPTCL:

Implementation of Special Protection Scheme (SPS) to take care of over-loading of the other

ICT when one out of two ICT‟s operating in parallel trips.

Provision of Bus-bar protection to 220 kV buses.

Compliance of Third Party Protection Audit Recommendations.

Ensuring supply reliability to Metro-services.

Action plan on the proposed system strengthening measures in Bengaluru area in the context of

continued use of Split-Bus operation.

35.2 To ascertain the action taken by KPTCL w.r.t. above issues, a Protection System Analysis Group

(PSAG-18) meeting had been conducted on 3rd

July, 2017 at 400/ 220/ 66 kV Hoody SS of KPTCL

with participation of Officials from Hoody SS, KPTCL Head Quarters, SLDC-KPTCL, SRLDC, and

SRPC.

With respect to SPS proposed, it was noted that the same had been put in place, and would be

put into operation after conducting a mock-test.

It was noted that provision of BBP to 220 kV buses and complying with Protection Audit

Recommendations will be completed by September, 2017.

With respect to ensuring supply reliability to Metro-services, it was noted that supply

redundancy has been ensured with the newly commissioned Majestic station, which with its 33

kV switchgear has made possible the ring-bus operation of four ends of the metro-service.

It was also noted that KPTCL has concrete proposals to commission four new 400/ 220 kV GIS

substations at Mylasandra (tendering stage), Dommasandra (admin. approval stage), Devanahalli

(tendering stage), and Peenya (Cost estimates stage). KPTCL informed that they would be

commissioned in one-and-half years from the date of award of respective contracts.

On the sidelines of above meeting, status-check of various protection settings adopted and

protection practices being followed were also reviewed and suitable modifications were

suggested for kind compliance.


KPTCL had informed that bus bar protection, composite protection, differential protection, Main 2

Relay, SPS etc works were being taken up. Complete revamp of the station was also being carried

out. All recommendations of the PSAG were being addressed.

KPTCL was suggested to give required priority to address these issues.


36. PROTECTION AUDIT OF SUBSTATIONS IN SOUTHERN REGION CONDUCTED

DURING MARCH – AUGUST, 2017

36.1 Hon‟ble CERC vide their Order dated 27.04.2015 in respect of APTRANSCO Petition

No.95/MP/2015 dated 09.04.2015 had directed SRPC to conduct protection audit of substations in

Southern Region and submit a bi-monthly report of periodic protection audit details to Hon'ble

Commission.


In this regard, following substations had been protection audited during the period March – August,

2017:

Sl.

No.

Name of the Station audited Period of Audit Composition of Audit

Team

1 400/ 220 kV Shankarapally SS of

TSTRANSCO

20 – 21 March, 2017 SRPC, SRLDC &

PGCIL (SR-I)

2 765/ 400 kV Nellore PS of PGCIL

(SR-I)

19 – 20 June, 2017 SRPC, SRLDC,

APTRANSCO &

TPCIL

3 230/ 110 kV Villianur SS of PED

10 July, 2017 SRPC, SRLDC &

NLCIL

4 230/ 110 kV Bahour SS of PED

11 July, 2017 SRPC, SRLDC &

NLCIL

Remarks furnished by the protection audit teams for the above stations are enclosed at Annexure-

LIII. TSTRANSCO, PGCIL (SR-I), and PED were requested to take suitable action to comply

with the remarks given.

36.2 SRPC suggested the concerned entities to initiate necessary action to comply with the Protection

Audit remarks.

37. AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE TRANSMISSION

LINES OF SOUTHERN REGION

37.1 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.

37.2 Provision for Auto-Reclosure is also mandated by Regulation 43 (4) (c) of CEA Technical

Standards for Construction of Electrical Plants and Electric Lines, 2010, which has force of law.

Therefore, it is in the interest of grid security that all Constituents implement auto-reclosure feature

on all 220 kV & above transmission lines in their respective control areas. Any exceptions to this

needed to be properly justified.

37.3 Details w.r.t. A/R implementation status on all 220 kV & above transmission lines in SR-grid has

been collected. Based on the information furnished by various SR-Utilities, it was noted that the

main issues in implementing A/R are the adopted conservative protection philosophies, lack of

proper PLCC communication, and breakers‟ suitability/ supportability. Hence, it is intimated that

if there are no issues w.r.t. carrier communication and breakers’ supportability, concerned

Constituents shall make efforts to implement A/R immediately in their respective networks.

Where communication & breaker related issues stand in the way of implementing A/R,

concerned Constituents shall take steps to address them appropriately on priority basis, and

implement A/R in their respective networks in a phased manner at the earliest.

37.4 Logics for implementing A/R have been clarified in various PCSC meetings as follows:

Normally, high speed, single-ph, single-shot A/R scheme (with simultaneous opening at both

ends of feeder with a dead-time of 1 sec and reclaim-time of 25 sec) may be used by all Utilities

(including Generators).


However, those generators (Coal/ Gas/ Nuclear/ Hydro) who have concerns w.r.t. closing on to

un-cleared fault can make use of the following time-differentiated single-ph, single-shot A/R

scheme:

“In this, after a line has been opened from both ends (generator end & grid end) on A/R

operation, the grid end will be auto-reclosed as usual after the elapse of its dead-time (say, 1

sec). However, the generator end relay will check for the line voltage after elapse of an

extended dead time, say 1.5 sec [here the additional time delay of 0.5 sec, which has been

included as a safety margin, shall be so chosen that the extended dead-time is less than the

adopted Pole Discrepancy time delay]. If the line voltage so sensed is healthy & normal

(which implies that the fault has already been cleared), then generator end will be auto-

reclosed; else 3-ph trip will be given at generator end to open the other two phase poles.”

Further, wherever Trip-on-Reclose (ToR) feature is available at grid-end station, it shall be

configured such that it sends Direct Trip (DT) command to generator end upon its operation.

The above scheme can be as it is used to Line-CB‟s of all bus configurations (including Main-

CB‟s of one-and-half breaker bus configuration). For Tie-CB‟s in one-and-half breaker

configuration employing priority scheme (which also happens to be the recommended practice),

above logic is not be required since the employed priority scheme anyway checks for

CLOSE_STATUS of Main-CB before closing Tie-CB. However, if required, the above logic can

be applied to Tie-CB‟s also by adopting a suitable extended dead-time considering the remote end

station‟s A/R dead time.

A/R functionality for a transmission line shall be preferably put into service using (i) Bay

Control Unit (BCU) or (ii) separate External A/R Relay. Where, these are not available, only

then should the A/R functionality of Main protection relays of lines be used. Here, it is assumed

that both Main-relays are deriving their Voltage Input from the Line CVT‟s (from different cores,

as per the recommended practice). However, if this is not the case and the concerned Utility has a

practice of using Line-CVT voltage input to one of the Main relays and Bus-CVT voltage input to

the other Main relay, it is recommended that voltage input to be used in time-differentiated A/R

logic shall be exclusively derived from the line-CVT for use in both the Main relays.

A/R implementation is not required in case of radial feeders, cables, & composite feeders, and is

optional for the lines interconnecting two generating stations. Status is given in Annexure- LIV.

In addition to above, the following logics (applicable to the Cases where A/R is being/ proposed

to be implemented from Main Protection Relays) have also been intimated for the benefit of the

Constituents:

Since there are two Main protection relays (Main-I and Main- II), to decide upon proper way of

implementing A/R for achieving fool-proof A/R operation, it has been advised that instead of

implementing A/R from only one of the Main relays (in view of its low success rate), the

following Alternatives be considered:

Alternative – 1: A/R is implemented and kept functional from Main – I [Main-II] only, but with

feedback from Main-II [Main-I]

In this scheme, A/R is implemented and kept in service from Main-I [Main-II] as usual.

Additionally, Main-II [Main-I] relay is configured for single-pole (1-ph) tripping, and the OPEN

(TRIP) status of the concerned trip relay is used for triggering A/R functionality in Main-I [Main-

II]. By this, even if the fault is not sensed in the beginning by Main-I [Main-II], but sensed by

Main-II [Main-I], A/R operation is guaranteed. However, it may be noted that in cases of

permanent faults, this scheme may result in unsuccessful A/R operation with Pole Discrepancy

Relay coming to rescue if the fault is not sensed by Main-I [Main-II] but by Main-II [Main-I] at

the time of auto-reclosing instant.


Alternative – 2: A/R is implemented and kept functional from both Main – I and

Main-II.

In this scheme, A/R is implemented and kept in service from both Main – I and Main-II as usual.

As can be seen, the scheme is reliable and is without any additional logics. However, to avoid the

possibility of both relays racing for CLOSE-OPEN-CLOSE-OPEN operation in the event of

permanent faults, it shall be ensured that along with other conditions, “A/R BLOCK with 3-ph

TRIP” is also affected for the same phase fault as the original one that occurs during A/R dead-

time.

Out of the above two also, it had been suggested to consider Alternative-2 in view of its higher

success rate of A/R operation.

37.5 SRPC suggested the concerned entities to complete the activities in a time bound manner.

38. IMPLEMENTATION OF LINE DIFFERENTIAL PROTECTION (LDP) IN NELLORE AND

SIMHADIRI COMPLEXES

38.1 The following may kindly be noted in respect of LDP implementation:

Complex Constituents responsible for implementation

Nellore PGCIL (SR-I), APGENCO, APTRANSCO, TPCIL,

SGPL, MEPL and SEL

Recommendation to implement LDP on all 400 kV transmission lines in Nellore Complex

(except Gooty line) was originally given by PCSC forum in their 50th

Meeting held on 27.01.2016

w.r.t. TPCIL station outage on 30.12.2015 at 06:02 hrs.

The same was reiterated by PCSC forum in their 57th

Meeting held on 02.09.2016 w.r.t. tripping

of various lines in Nellore complex on 18.07.2016 at 19:05 hrs. In this meeting, it was also

decided that PGCIL (SR-I) would convene a meeting with all stakeholders involved, viz., TPCIL,

SGPL, MEPL, SEL, APTRANSCO, SDSTPS and APGENCO to finalize the modalities for

implementing the same.

The issue was again discussed in the 64th

Meeting of PCSC held on 25.05.2017 to ascertain the

status of implementation when PGCIL (SR-I) informed that consequent to decision taken PCSC-

57 meeting, a meeting had been convened with all stakeholders involved, and it was agreed that

PGCIL (SR-I), in addition to their own requirement, would also procure LDP relays on behalf of

other stakeholders involved after obtaining their written consent. Subsequently, TPCIL & SGPL

had given their written consent to PGCIL (SR-I); however, the same was still awaited from

MEPL and SEL. PGCIL (SR-I) also informed that they had taken up the issue with their

management regarding procurement of LDP relays in Nellore, Simhadri, and Raichur Complexes

required for PGCIL (SR-I) and other stakeholders who had given written consent to procure on

their behalf.

When APTRANSCO was enquired about the present status, it was informed that they had

recently held a meeting with APGENCO and SDSTPS, and it was decided that APTRANSCO

would procure LDP relays required for their own and on behalf of APGENCO and SDSTPS.

PCSC forum noted that there had been a considerable delay in taking required action by the

Constituents responsible for implementing LDP. Thus to ensure that the issue is given due

importance (considering the criticality of Nellore Complex), it was agreed that Line Differential

Protection would be implemented in Nellore Complex on all 400 kV lines (< 50 km) by

December, 2017.

Subsequently MEPL (vide their mail dated 14.06.2017) and SEL (vide their mail dated


27.06.2017) had informed that in view of their present financial condition, they may kindly be

exempted for the time being, from implementing LDP on the lines belonging to them in Nellore

Complex. However, they assured that suitable action would be taken to implement the same once

the situation improved.

Complex Constituents responsible for implementation

Simhadri PGCIL (SR-I), NTPC, APTRANSCO and HNPCL

Recommendations to implement LDP on all 400 kV transmission lines in Simhadri Complex was

originally given in the Special meeting held on 04.05.2016 on issues relating to Grid Disturbances

in Kalpaka – Gajuwaka – Hinduja – Simhadri (KGHS) Corridor during 24 – 26 April, 2016.

The same was reiterated in the 17th

Meeting of Power System Analysis Group (PSAG-17) held on

3-4 October, 2016 at NTPS-Simhadri, Kalpaka SS, and Hinduja TPS.

The issue was again discussed in the 64th

Meeting of PCSC held on 25.05.2017 to ascertain the

status of implementation when PGCIL (SR-I) informed that in addition to their own requirement,

they would also procure LDP relays on behalf of NTPC-Simhadri, and the issue had already been

taken up with their management regarding procurement of LDP relays in Nellore, Simhadri, and

Raichur Complexes.

When APTRANSCO was enquired about the present status, it was informed that based on the

parleys they had held with HNPCL, it was decided that APTRANSCO would procure LDP relays

required for their own and on behalf of HNPCL.

PCSC forum noted that there had been a considerable delay in taking required action by the

Constituents responsible for implementing LDP. Thus, to ensure that the issue is given due

importance (considering the criticality of Simhadri Complex), it was agreed that Line

Differential Protection would be implemented in Simhadri Complex on all 400 kV lines inter-

connecting Gajuwaka SS, Kalpaka SS, Simhadri STPP and Hinduja TPS by December, 2017.


PGCIL had agreed to coordinate with the concerned entities and complete the works by

December 2017.

APTRANSCO had informed that the works in their scope would be completed within 3-4

months.

All concerned entities were suggested to coordinate with PGCIL and complete work within their

scope.


39. PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS

39.1 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. TSTRANSCO/APTRANSCO to add Kothagudem-Lower

Sileru line in the list lines to be patrolled. Format for furnishing details of schedule / Patrolling and

Maintenance carried out of the critical Transmission lines and Substations had been circulated.

39.2 Concerned entities needed to kindly initiate/continue necessary steps to ensure that Patrolling and


Maintenance is carried out regularly as per the Patrolling Guidelines.


40. COMPLIANCE OF ORDER OF HON‟BLE CERC IN PETITION NO. 420/MP/2014 – IN

RESPECT OF LVRT AND OTHER PROVISIONS OF CEA/CERC REGULATIONS

40.1 Three Meetings had been conducted so far in compliance of Order of Hon‟ble CERC (Petition

No.420/MP/2014) in respect of LVRT and other provisions of CEA/CERC Regulations. Hon‟ble

Commission had specified time lines for a number of actionable points for various entities.

40.2 Quarterly reports for the period January-March 2017 of the SR constituents jointly validated by

SRLDC/SRPC Secretariat had been communicated to Hon‟ble CERC with regard to monitoring of

the installation and performance of LVRT installed on existing WTGs as per the directives of

Hon‟ble CERC.

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

Grid) Regulations and comments had been sought till 31.01.2017. The final notification is awaited.


New wind and solar units need to comply with LVRT/HVRT provisions and STU/SLDC was

to ensure necessary compliance. Required mechanism needs to be in place for this purpose.

SLDCs were requested to approve connectivity to new generators only on confirmation of

availability of LVRT feature and other CEA/CERC requirements. Monthly report of

compliance needs to be furnished for new wind/solar generators added to the grid.

SRLDC had pointed out that PMU at Pooling station was required to assess LVRT

performance.

SRLDC had requested that SLDCs may kindly prepare a geographic picture of the Wind/Solar

generators and extend it to SRLDC through ICCP. Later it can be integrated to Regional

Picture. In the REMC project extension of data was to be carried out by states and action now

would make it easier subsequently.


41. PENDING IMPLEMENTATION OF RECOMMENDATIONS OF PROTECTION

COORDINATION SUB-COMMITTEE (PCSC) OF SRPC

41.1 Recommendations given in various PCSC Meetings to SR-Constituents are being sent regularly to

the concerned Constituents for implementation. Update of the consolidated list of pending PCSC

recommendations (up to the 64th

Meeting) for implementation by SR-Constituents is enclosed in the

Minutes of PCSC.

41.2 SRPC suggested that respective entities may take necessary action to close the pending issues.

42. COMMERCIAL COMMITTEE ISSUES

42.1 Following issues were brought to the attention of SRPC:

Assessment of Metering requirement

SRTS I, PGCIL, STUs, Generators and IPPs were requested to submit the SEM requirements

and procurement plan as per CEA Metering regulations for the upcoming projects to

SRLDC/SRPC Secretariat.


Utilities were recommended to maintain 10% of existing No of SEMs as Spare and sufficient

number of DCDs.

Delay in SEM data transfer

SRLDC had informed that the some of the entities are not sending SEM data within time, in

line with IEGC Clause 6.4.21.

CC Forum had expressed concern that the issue of non receipt of SEM data persists, even

though the effect on the accounting and possible losses had been brought to the notice of SR

constituents time and again.

Time drift statement non-receipt status

SRLDC had informed that the following stations were not sending the monthly time drift

statements:

Constituents Stations

Karnataka Ambewadi, Guttur,Kodasalli, Kadra, Sedam, Alipura

AP Kurnool, KV Kota, VTPS, Ragulapadu & Uravakonda

TN Arni, Gummidpoondi, Achrapakkam, SP Koil

Telangana Alampur, Wanaparthy & Tandur

SRTS I Srikakulam, Vemagiri

Goa Xeldem & Ponda

Online Uploading of SEM data by the constituents

SRLDC informed that the SEM data to be uploaded by the stations in the website module

developed by SRLDC in the following link instead of sending it by Email every week:

http://scheduling.srldc.org:8080/meterfile/

SEM data may be uploaded latest by every Tuesday beyond that time the software won‟t

allow uploading.

Status of Start-up power drawl, Infirm injection and CoD Declaration

Start Up Power

Sl.No Generator Startup power granted

From To

1 Kudgi U-3 20-02-17 31-12-17

Infirm Power

Sl.No Generator Infirm

Injection

started from

6 month period

would end by

COD

1 Kudgi U-1 28-11-16 27-05-17 31.07.2017

2 SGPL U-2 02-02-17 21.02.2017

3 Kudgi U-2 18-02-17 31-01-18

(Advance action may be taken in the likelihood of delay in declaring CoD beyond 6

months)

PSDF Transfer The status of fund transfer from SR to PSDF as on 10.04.17 is as given below:

(In Rs. Crores)





UI/DSM A/c.

(Including

capping A/c.)

Reactive

A/c.

e-bidding

charges

Congestio

n Amount

Grand Total

Total (Up

to Jul‟16)

1135.68596 3.7940429 556.31078 2.41198 1901.62276

Mar‟17 0 0 0.35219 0 0.35219

Total (Up

to Mar‟17)

1135.68596 3.7940429 556.66297 2.41198 1901.97495

No amount is being transferred to PSDF since Aug‟16 in order to keep sufficient surplus

funds to meet RRAS deficit in pool accounts of all RLDCs. An amount of Rs 81.08 Cr was

transferred to NRLDC deviation pool account.


43. MONITORING OF SCHEMES FUNDED FROM PSDF

43.1 It was noted that in a Meeting held on 29th

April 2016 chaired by Joint Secretary (OM), MoP to

review status of implementation of the schemes funded from PSDF, it was felt prudent that

respective RPC Secretariat monitor the schemes approved in its region, in addition to the

Monitoring Group at Central level, as part of monthly Meetings, in view of slow progress of the

implementation of the schemes. The entities are to furnish the information in the specified format

by first week of every month on regular basis to Member Convener, PSDF Project Monitoring

Group (AGM, NLDC, and POSOCO) with a copy to NPC Division. List and status of PSDF

funded schemes is furnished at Annexure-LV.

43.2 NLDC had convened a Meeting at NRLDC, New Delhi on 20th

June 2017 to discuss progress of

works of schemes and assess the actual Status.


NPC had informed that around Rs 9,400 crores of schemes had been sanctioned. However, the

actual utilization was only Rs 600 crores (7%). KSEBL and TANTRANSCO had utilized 20-

30%, while utilization by others was quite meager. Since the fund is earmarked, it cannot be

allotted to other needy utilities. It was suggested to utilize the funds in the identified projects in

a time bound manner.

APTRANSCO had informed that the processing of tendering etc consumed time since there are

stipulated guidelines which need to be adhered to. Bulk expenditure was expected now and

would be claimed for disbursal and the time line for completion of the project would be met.


44. SCHEDULING OF KAMUTHI SOLAR PARK

44.1 Two Meetings had been convened on 03rd

November 2016 and 23rd

December 2016 at SRPC,

Bengaluru to discuss scheduling and dispatching responsibility in respect of Adani Solar Power

Project at Kamuthi in Tamil Nadu. Minutes of the two Meetings are available in SRPC website. In

the Meeting held on 23.12.2016, the following was concluded:

„After deliberation it was decided that M/s. AGEL would obtain legal advice and submit the

same to SRPC & SRLDC. Subsequently SRPC would refer the matter to CEA for legal


advice. Tamil Nadu was also requested to consider furnishing their inputs to SRPC/CEA at

the earliest.‟

44.2 The legal opinion of M/s AGEL and POSOCO was referred to CEA. CEA, Legal Division vide

letter dated 30.03.2017 (Annexure-LVI) had concluded that as per advice sought by the SRPC the

scheduling of the Solar Power Project can be scheduled under the provisions of IEGC

(Regulation 6.4.2(b) by SRLDC. SRLDC vide letter dated 10.04.2017 (Annexure-LVII) had

informed that SRLDC can schedule power from M/s AGEL and its subsidiaries. However, in order

to avoid any difficulties at a later date it had been suggested that M/s AGEL may seek directions

from Hon‟ble CERC in resolving the difficulties mentioned before SRLDC can begin scheduling of

the generating station under IEGC Regulation 6.4.2(b).

44.3 A Meeting to discuss further course of action on scheduling etc was proposed to be held on 14th

August 2017.


45. AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM

45.1 KSEBL vide letter dated 25th

September 2015 had stated that since all Southern states would get

benefitted with the early commissioning of Talcher-II transmission system, all SR Constituents may

jointly implead as a party in the Civil Appeal filed by TNEB before Hon‟ble Supreme Court. In the

27th

TCC Meeting it was suggested that SR constituents may jointly implead as a party in the Civil

Appeal filed by TNEB in Honorable Supreme Court.

45.2 Hon‟ble Commission in its Order dated 05.11.2015 in respect of Petition No. 14/SM/2015, in the

matter of „Notice under Section 19 of the Electricity Act, 2003 for revocation of the inter-State

transmission licence granted to Talcher II Transmission Company Ltd.‟ had passed the Order :

„13. In exercise of our power conferred under Section 19 (3) of the Act and Regulation 20 of the

Transmission Licence Regulations notice is given to the licensee to show cause within three

months from the date of this order as to why the transmission licence granted for the

transmission project should not be revoked in terms of the provisions of Section 19 of the

Electricity Act and Transmission Service Regulation as quoted above. If no response is received

within three months from the date of issue of the order, the licence shall be deemed to have been

revoked.‟

45.3 In earlier Meetings, the following had been deliberated:

TANGEDCO had informed that after CERC‟s Order referred in the agenda, M/s Reliance had

approached APTEL. Revised cost submitted by the M/s Reliance is around 2.5 to 3 times the

original cost. APTEL had advised Reliance to approach all the LTTCs for seeking consent for

Reliance to carry out the works at enhanced cost. Reliance had convened a meeting but none of

the LTTCs had attended and now they have taken up the issue through letters. Next hearing in

APTEL was scheduled in 1st week of April 2017.

KSEBL had suggested for Joint Study to assess requirement of Talcher II augmentation system

in the present scenario.


TANGEDCO had informed that the Petition was scheduled for hearing before APTEL on 22nd


August 2017. In their affidavit, they had made it clear that this system was no more required.

As per their studies, considering Jharsuguda-Angul system in ER, 765 kV & 400 kV

transmission system commissioned/under execution/planned in SR/ER there were no

constraints envisaged for evacuation of Talcher Stage-II power in ER & SR during outage of

single pole of HVDC.


46. GRID OPERATION

46.1 Salient Achievements

Merit Order Dispatch Data portal had been made operational. Contribution of constituent states

was placed on record.

In July, SR witnessed highest ever wind injection (198.87 MU) on 17.07.2017 as given below:

Generation

(MU)

AP

TS

KAR

KER

TN

SR

WIND 57.74 1.48 44.98 0.62 94.05 198.87

Capacity of Wind + Solar had crossed 20 GW in SR.

Black start Mock Drill for extending from power from Upper Sileru to NTPC Simhadri was

successfully completed on 20th

June 2017. Efforts of APTRANSCO, APGENCO, PGCIL,

NTPC Simhadri, SRLDC, NLDC and ER counterparts were placed on record

Black start Mock Drill for extending from power from Eastern Region to NTPC Simhadri

through HVDC Gazuwaka AC Bypass switch was successfully completed on 22.06.2017.

Capacity building Workshop on STOA procedures conducted on 19.05.2017 at SRLDC.

SEM Workshop for Tamil Nadu was conducted on 26.05.2017 at Kanarapatti.

Workshop on first time Synchronization of Transmission elements conducted on 21.04.2017

by SRLDC.

Black Start Restoration Procedure of SR 2017 was released by SRLDC.

Andhra Pradesh SLDC had been shifted to Vijayawada.

NTPC had crossed 50 GW all India Generation Capability in March 2017.

KPCL had recorded maximum generation during the year 2016- 2017.

BSRP coordinators Workshop was successfully completed from 20th

to 22nd

March 2017.

Support extended by all the constituents during Talcher-Kolar shut down during March 2017.

IMD workshop had been organized by SRLDC on 12.07.2017 to derive maximum benefit for

load and RE forecasting.

SEM based drawal philosophy had been implemented for all Southern States.

SEM Workshop for Telangana & Kerala had been conducted on 23.06.2017 & 07.07.2017.

46.2 Grid Events/ Highlights during February 2017

Karnataka met highest ever Demand of 10242 MW on 24.02.2017 & highest energy

consumption of 222 MUs.

Andhra Pradesh added 180 MW Solar in the Installed Capacity (Private Sector).

Karnataka added 12 MW (1 Plant) in Wind Installed Capacity and 129 MW (23 Plants) in

Solar Installed Capacity during the month. (Private Sector)

Tamil Nadu added 26.35 MW in Wind Installed Capacity during the Month (Private Sector).

400 kV Kudgi (NTPC) – Kudgi (PG) III was first charged on 24.02.2017 at 03:31hrs by KTL.

400 kV Kudgi (NTPC) – Kudgi (PG) IV was first charged on 24.02.2017 at 04:36 hrs by KTL.

765/400 ICT-I at Srikakulam idle charged on 25.02.2017 at 05:44 hrs by PGCIL.


Nizamabad - I bay at Dichpally was commissioned on 25.02.2017 at 02:21 hrs.

Nizamabad - II bay at Dichpally was commissioned on 25.02.2017 at 02:52 hrs.

400 kV Suryapet –KV Kota I was commissioned on 28.02.2017 at 07:09 hrs.

400 kV Suryapet –KV Kota II was commissioned on 03.02.2017 at 02:27 hrs.

400/220 kV ICT-I KV Kota (315 MVA) was commissioned on 28.02.2017 at 07:40 hrs

400 kV Gajwel- Narsapur I was commissioned on 03.01.2017 at 11:57 hrs

400 kV Narsapur- Shankarapalli I was commissioned on 03.01.2017 at 03:34 hrs

400 kV NPS – Nellore 125 MVAR reactor was commissioned on 03.02.2017 at 07:21 hrs

ICT III at Kozhikode first time charged on 03.07.2017 at 07:06 hrs by PGCIL.

220 kV D/C line from 220/11 kV Yellanur SS to 220/11kV Gaddamavaripali SS in YSR

district of 9.33 ckm was commissioned on 04.02.2017 by APTRANSCO.

220 kV D/C line from 220/11kV Gaddamavaripalii SS to 220/11kV Goddumarri SS in YSR

district of 18.23 ckm was commissioned on 15.02.2017 by APTRANSCO.

220 kV D/C line from 220 kV Gani PS-4 to 400 kV Gani SS in Kurnool district of 5.40 ckm

was commissioned on 25.02.2017 by APTRANSCO.

220/11 kV LIS SS at Gaddamavaripalli in YSR district of 50 MVA Capacity was

commissioned on 04.02.2017 by APTRANSCO.

220/11 kV LIS SS at Goddumari in YSR district of 100 MVA Capacity was commissioned on

15.02.2017 by APTRANSCO.

220/33 kV SS at Gani PS-4 in Kurnool district of 240 MVA Capacity was commissioned on

PT Rs 3 & 4 23.02.2017 & PTR 2 28.02.2017 by APTRANSCO.

220 kV SS at Rajampet in YSR Dist of 1 x 100 MVA existing Capacity was augmented to a

capacity of 2 x 100 MVA and was commissioned on 28.02.2017 by APTRANSCO.

220 kV XLPE UG Cable from Chandrayanagutta SS to Imliban GIS Substation in Hyderabad

district of 9.5 ckm was commissioned on 15.02.2017 by TSTRANSCO.

220/132 kV Imliban GIS SS (PTR – I) in Hyderabad District of 160 MVA capacity was

commissioned on 02.02.2017 by TSTRANSCO.

400/220/132kV SS at Gajwel in Siddipet Dist of 1 x 160 + 2 x 100 MVA existing Capacity

was augmented to a capacity of 2 x 160 + 1 x100 MVA and was commissioned on 20.02.2017

by TSTRANSCO.

SR II, Power grid vide letter dated 16.03.2017 had informed that the following asset under

“System strengthening in Southern Region - XXIII” shall be put under Commercial Operation

w.e.f 00:00 hrs of 16.03.2017:

Replacement of 3 x 167 MVA, 400/220 kV ICTs with 1 x 500 MVA ICT at Somanahalli SS

(The replaced ICTs shall be maintained as a regional spare).

46.3 Grid Events/Highlights during March 2017

Tamil Nadu added 144.75 MW in Wind Installed capacity (Private sector).

Southern Region witnessed highest ever demand of 42177 on 03.03.2017

Southern Region met highest ever energy consumption of 993.67 MU on 31.03.2017.

Karnataka met highest ever energy consumption of 229 MUs

Telangana met highest ever energy consumption of 195 MUs

SPS mock tests for Talcher – Kolar, RCR-SLPR, KKNPP Unit I & II completed

400 kV Gajwel-Narsapur was charged on 01.03.2017 at 15:34 hrs by TSTRANSCO.

400 kV Narsapur-Shankarpalli was charged on 02.03.2017 at 02:36 hrs by TSTRANSCO.

400 kV 315 MVA ICT-II at Suryapet was charged on 17.03.2017 at 16:41 hrs by

TSTRANSCO.


400 kV 315 MVA ICT-III at Dichpally was charged on 24.03.2017 at 15:42 hrs by

TSTRANSCO

400 kV Dichpally-Nizamabad ckt II was charged on 24.03.2017 at 16:22 hrs by

TSTRANSCO

220 kV D/C line from 220 kV Kamavarapukota SS to 400kV Kamavarapukota SS in West

Godavari district of 9.00 ckm was commissioned on 04.03.2017 by APTRANSCO.

220 kV D/C line from 220 kV Appayyadorapalem SS to Bobbili SS in Vizianagaram district

by APTRANSCO.

220 kV D/C line from 220 kV Palamaneru to proposed 220 kV Kuppam SS in Chittoor district

of 131.54 ckm was commissioned on 30.03.2017 by APTRANSCO.

220 kV D/C line from 220 kV PS-1 to 400 kV Gani SS in Kurnool district of 6.43 ckm was


220 kV D/C line from 220 kV PS-3 to PS- 4 in Kurnool district of 7.412 ckm was


PTR-1 at 220/33 kV Gani PS-4 in Kurnool district of 80 MVA Capacity was commissioned on


Transformer at 220/132 kV SS Kuppam in Chittoor district of 100 MVA Capacity was


PTR 4 at 220/33 kV SS at Gani PS-1 in Kurnool district of 80 MVA Capacity was


PTR 3 & PTR 4 at 220/33 kV SS at Gani PS-3 in Kurnool district of 160 MVA Capacity were

commissioned on 31.03.2017 & 28.03.2017 by APTRANSCO

220 kV UG Cable and OH multi ckt line from 220 kV Ghanapur SS to 220 kV Hayathnagar

Substation of 48 ckm was commissioned on 13.03.2017 by TSTRANSCO.

220 kV Dindi-Bonguluru LILO to 400/220 kV Maheshwaram SS of 18 ckm was


At 400 kV Gajwel SS of 125 MVAR Capacity was commissioned on 31.03.2017 by

TSTRANSCO.

SR II, Powergrid vide letter dated 28.03.2017 had informed that the following asset under

transmission system associated with “System strengthening –XX in Southern Regional Grid”

have been put under Commercial Operation w.e.f 00:00 hrs of 28.03.2017:

Conversion of 50 MVAR line reactors at Madakathara end on both circuits of Ellapally

(Palakkad) – Madakathara (North Thrissur) 400 kV D/C line into switchable reactors by

providing necessary switching arrangement.

SR II, Power grid vide letter dated 28.03.2017 had informed that 1 No. of 500 MVA, 765/400

kV Regional spare ICT at Thiruvalam Substation under „System Strengthening in Southern

Region-XXIII” is ready for intended use and have been put under Commercial Operation w.e.f

00:00 hours of 28.03.2017.

SR II, Power grid vide letter dated 30.03.2017 had informed that OPGW communication links

along with associated Communication Equipment as per the list enclosed under the Project

“Fibre Optic Communication System for Central Sector Sub-Stations & Generating Stations in

Southern Region” are successfully commissioned. The above assets are put into service for

commercial operation w.e.f 30.03.2017.

The charges for the above assets are payable from 30.03.2017 as being approved by CERC and

the same will be communicated separately.


SR I, Power grid vide letter dated 03.04.2017 had informed that the following asset under

“Wardha – Hyderabad 765 kV Link” have been put under Commercial Operation w.e.f 00:00

hrs of 02.04.2017:

Nizamabad – Wardha 765 kV D/C Line along with associated bays and equipment

Nizamabad – Dichpalli 400 kV D/C Line along with associated bays and equipment

765/400kV GIS Substation at Nizamabad with 3 x 500 MVA ICT-I along with associated

bays and equipment

3 x 80 MVAR 765 kV Bus reactor at Nizamabad 765/400 kV Substation

3 x 80 MVAR line reactor at Nizamabad 765/400 kV Substation for 765 kV Nizamabad –

Wardha – I

3 x 80 MVAR line reactor at Nizamabad 765/400 kV Substation for 765 kV Nizamabad –

Wardha – II SR I, Powergrid vide letter dated 03.04.2017 had informed that the following asset under

“System Strengthening in Southern Region –XX” have been put under Commercial Operation

w.e.f 00:00 hrs of 27th

March 2017:

1 x 125 MVAR, 400 kV Bus Reactor-3 along with associated bays and equipment at

Vijayawada Substation.

1 no. 400/220 kV 500 MVA ICT-3 along with associated bays and equipment at

Hyderabad Substation.

1 no. 400/220 kV 500 MVA ICT-3 along with associated bays and equipment at


SR I, Powergrid vide letter dated 03.04.2017 had informed that the following asset under

“System Strengthening in Southern Region –XXIII” have been put under Commercial

Operation w.e.f 00:00 hrs of 28.03.2017:

1 x 125 MVAR, 400 kV Bus Reactor-2 along with reactor bay and equipment at Gooty

Substation.

1 x 125 MVAR, 400 kV Bus Reactor-2 along with reactor bay and equipment at

Khammam Substation.

1 x 125 MVAR, 400 kV Bus Reactor-2 along with reactor bay and equipment at Nellore

(existing) Substation.

1 x 125 MVAR, 400 kV Bus Reactor-2 along with reactor bay and equipment at

Nagarjunasagar Substation.

1 x 63 MVAR switchable line reactor at Nellore PS for 400kV Gooty – Nellore PS-I.

1 x 63 MVAR switchable line reactor at Nellore PS for 400kV Gooty – Nellore PS-II.

SR I, Powergrid vide letter dated 03.04.2017 had informed that the following asset under

“System Strengthening in Southern Region –XX” have been put under Commercial Operation

w.e.f 00:00 hrs of 02.04.2017:

1 x 125 MVAR, 400 kV Bus Reactor-4 along with associated bays and equipment at


SR II, Powergrid vide letter dated 03.04.2017 had informed that the following asset under “Sub

Station Extension works associated with transmission system required for evacuation of power

from Kudgi TPS (3 x 800MW in Phase I) of NTPC Limited” have been put under Commercial

Operation w.e.f 00:00 hrs of 03.04.2017:

2 Nos 400 kV Line bays at Bidadi for Madhugiri (Tumkur) – Bidadi 400 kV D/C (Quad)

line.


46.4 Grid Events/Highlights during April 2017

Tamil Nadu added 5.55 MW in Wind Installed capacity (Private sector).

Tumkur-Nelamangala –Bidadi rearrangement normalized.

5th IEGC Amendment Regulations notified.

Simhadri Stage I Scheduling started from 01.05.2017.

220 kV D/C line from 220 kV PS-II SS to 400 kV Gani SS in Kurnool district of 1.688 ckm

was commissioned on 17.04.2017 by APTRANSCO.

220 kV LILO (Both circuits) from 220 kV Hindupur SS to Pulivendula DC line to proposed

220kV SS Gollapuram in Anantapur district of 156 Ckm was commissioned on 22.04.2017 by

APTRANSCO.

220 kV DC/SC line from 220 kV SS Malyala to 220 kV LIS Machumarri SS in Kurnool

district of 30 ckm was commissioned on 29.04.2017 by APTRANSCO.

220/33 kV Gani PS-2 in Kurnool district of 320 MVA Capacity was commissioned on


220/132/33 kV SS Gollapuram in Anantapur district of 150 MVA Capacity was


220/11kV LIS SS at Muchumarri in Kurnool district of 25 MVA Capacity was commissioned

on 29.04.2017 by APTRANSCO.

220 kV Twin Moose DC line from 400/220 kV Dichpally SS to 220/132 kV Dichpally feeder-

III Substation of 4.25 ckm was commissioned on 25.04.2017 by TSTRANSCO.

220 kV Twin Moose DC line from 400/220 kV Dichpally SS to 220/132 kV Dichpally feeder-

IV Substation of 4.25 ckm was commissioned on 28.04.2017 by TSTRANSCO.

46.5 Grid Events/Highlights during May 2017

Two STATCOMs (+/- 50 MVAR Each) at NP Kunta commissioned on 16.05.2017 by

PGCIL.

Kudgi Unit I 72 Hrs Trial Run completed successfully by NTPC.

Southern Region witnessed highest ever Wind generation of 168 MUs on 30.05.2017.

Tamil Nadu Wind generation touched 99.5 MUs highest till date.

400 kV Shankarapally-Suryapet I & II commissioned on 05.05.2017 by TSTRANSCO.

220/33kV SS at Hayathnagar I&II in Ranga Reddy district of 50 MVA Capacity was


SR II, Powergrid vide letter dated 10.06.2017 had informed that the following assets under

transmission system associated with “System strengthening –XX in Southern Regional Grid”

have been put under Commercial Operation w.e.f 00:00 hrs of 10.06.2017:

1 x 500 MVA, 400/220/33 kV ICT at Trichy Substation along with associated bays and

equipments.

SR I, Powergrid vide letter dated 04.06.2017 had informed that the following assets of

“Transmission System for Ultra Mega Solar Park in Anantapur Dist, Andhra Pradesh- Part –

A (Phase-I)” have been put under Commercial Operation w.e.f 00:00 hrs of 04.06.2017:

+/- 100 MVAR STATCOM at NP Kunta Pooling Station along with associated bays and

equipment.

46.6 Grid Events/Highlights during June 2017

AUFR, df/dt Joint Validation with states completed for Karnataka and Tamil Nadu as per

schedule.

Chittoor ICT I revived on 21.06.2017


Southern Region witnessed highest ever Wind generation of 186.13 MUs on 29.06.2017

220 kV LILO line from 220 kV Boothpur - Kalwakurthy Circuit I to the proposed to 220 kV

Switching station at Thimmajipet 4.40 Ckm was commissioned on 07.06.2017 by

TSTRANSCO

220 kV LILO line from 220 kV Boothpur - Kalwakurthy Circuit II to the proposed to 220 kV

Switching station at Thimmajipet district of 4.40 Ckm was commissioned on 07.06.2017 by

TSTRANSCO

220 kV SS at Switching Station at Thimmajipet district was commissioned on 07.06.2017 by

TSTRANSCO.

46.7 Grid Events/Highlights during July 2017

AUFR, df/dt Joint Validation with states completed for Telangana and Andhra Pradesh as per

schedule.

Bhadravathi HVDC bypass Mock drill exercise successfully completed on 21.07.2017

Southern Region witnessed highest ever Wind generation of 198.87 MUs on 17.07.2017

Tamil Nadu wind generation touched Maximum of 102.58 MU on 04.08.2017.

Kudgi Unit I COD was declared on 31.07.2017.

220 kV D/C line from 220 kV SS Uravakonda to 220kV SS Borampalli in Ananthapur district

69.6 Ckm was commissioned on 10.07.2017 by APTRANSCO.

Samalkota in East Godavari Dist of existing 100 MVA was commissioned on 15.07.2017 by

APTRANSCO with augmented capacity of 100 MVA.

220 kV LILO line from 220/132 kV Huzurabad SS Circuit I from Oglapur Durshad in

Karimnagar district was commissioned on 19.07.2017 by TSTRANSCO.

220/132 kV Huzurabad in Karimnagar Dist with 100 MVA capacity was commissioned on

19.07.2017 by TSTRANSCO.

SR I, Powergrid vide letter dated 27.07.2017 had informed that the following assets under

“Substation works associated with Hyderabad (Maheswaram) Pooling Station” have been put

under Commercial Operation w.e.f 00:00 hrs of 27.07.2017:

1 x 1500 Transformer-I along with associated bays and equipment at 765/400 kV GIS at

Hyderabad (Maheswaram).

2 numbers 240 MVAR 765 kV Bus Reactors along with associated bays and equipment

at Maheswaram SS.

Hyderabad (Maheswaram) – Kurnool 400 kV S/C line along with associated bays and

equipment at Maheswaram SS.

SR I, Powergrid vide letter dated 27.07.2017 had informed that the following assets under

“Wardha-Hyderabad 765 kV link” have been put under Commercial Operation w.e.f 00:00 hrs

of 27.07.2017:

Nizamabad-Hyderabad (Maheswaram) 765 kV D/C line

2 nos 765 kV bays at Nizamabad for terminating Wardha-Hyderabad (Maheswaram) 765

kV D/C line.

2 nos 765 kV bays at Hyderabad (Maheswaram) for terminating Wardha-Hyderabad

(Maheswaram) 765 kV D/C line.

1 no 240 MVAR switchable line reactor each at Hyderabad (Maheswaram) for both

circuits of Nizamabad-Hyderabad (Maheswaram) 765 kV D/C line.

1 no 240 MVAR switchable line reactor each at Nizamabad for both circuits of

Nizamabad-Hyderabad (Maheswaram) 765 kV D/C line.


46.8 Installation of Shunt Capacitors

Progress of installation of capacitors by the constituents during the year

2017-18 is furnished in the Table below:

(Figures in MVAR)

State Requirement

for 2017-18

Installed during the year

2017-18 up to July 2017

Andhra Pradesh 1639 91.6

Telangana 837.2 0

Karnataka 1633.7 128.6

Kerala 0 0

Tamil Nadu 100.8 19.2

Puducherry 45.8 0

46.9 Demand Variation (Peak Vs Off-peak)

Issue regarding large variation between minimum and maximum demands has been under the

consideration of TCC/SRPC. Issue is also being discussed in the monthly Meetings of OCC.

Following was observed with regard to the period from February 2017 to July 2017:

Description

Minimum to Maximum Demand Variation %

Andhra

Pradesh Telangana Karnataka Kerala Tamil Nadu

Puducherr

y

Southern

Region

February 2017

Highest 29.97 34.40 20.51 40.21 31.02 44.09 26.39

Date (Day) 12.02.2017

(Sunday)

02.02.2017

(Thursday)

13.02.2017

(Monday)

20.02.2017

(Monday)

13.02.2017

(Monday)

06.02.2017

(Monday)

24.02.2017

(Friday)

Lowest 18.01 27.39 11.18 29.97 15.60 25.11 8.88

Date (Day) 23.02.2017

(Thursday)

28.02.2017

(Tuesday)

15.02.2017

(Wednesday)

24.02.2017

(Friday)

26.02.2017

(Sunday)

05.02.2017

(Sunday)

26.02.2017

(Sunday)

Average 23.28 30.42 16.27 34.41 23.75 35.36 18.39

March 2017

Highest 28.62 32.36 20.95 37.36 29.37 38.37 17.46

Date (Day) 13.03.2017

(Monday)

15.03.2017

(Wednesday)

29.03.2017

(Wednesday)

17.03.2017

(Friday)

06.03.2017

(Monday)

26.03.2017

(Sunday)

03.03.2017

(Friday)

Lowest 15.68 20.14 11.02 24.07 12.61 19.83 7.15

Date (Day) 18.03.2017

(Saturday)

29.03.2017

(Wednesday)

28.03.2017

(Tuesday)

04.03.2017

(Saturday)

12.03.2017

(Sunday)

12.03.2017

(Sunday)

12.03.2017

(Sunday)

Average 20.86 26.97 15.78 31.50 19.89 29.67 12.57

April 2017

Highest 31.91 35.03 30.62 40.07 25.53 33.46 20.27

Date (Day) 29.04.2017

(Saturday)

04.04.2017

(Tuesday)

29.04.2017

(Saturday)

07.04.2017

(Friday)

26.04.2017

(Wednesday)

10.04.2017

(Monday)

17.04.2017

(Monday)

Lowest 13.27 14.15 12.19 20.84 6.11 15.72 8.04

Date (Day) 07.04.2017

(Friday)

23.04.2017

(Sunday)

25.04.2017

(Tuesday)

13.04.2017

(Thursday)

09.04.2017

(Sunday)

30.04.2017

(Sunday)

16.04.2017

(Sunday)

Average 23.25 23.86 16.48 28.94 16.32 25.20 11.50

May 2017

Highest 32.55 50.69 45.93 40.82 29.08 49.73 27.33

Date (Day) 01.05.2017 09.05.2017 08.05.2017 11.05.2017 23.05.2017 19.05.2017 08.05.2017


(Monday) (Tuesday) (Monday) (Thursday) (Tuesday) (Friday) (Monday)

Lowest 13.70 13.86 14.20 16.78 10.37 17.15 8.13

Date (Day) 23.05.2017

(Tuesday)

07.05.2017

(Sunday)

05.05.2017

(Friday)

10.05.2017

(Wednesday)

14.05.2017

(Sunday)

21.05.2017

(Sunday)

14.05.2017

(Sunday)

Average 23.15 23.19 25.20 30.68 17.56 25.86 15.81

June 2017

Highest 35.99 32.18 28.81 44.45 23.77 50.91 26.09

Date (Day) 05.06.2017

(Monday)

08.06.2017

(Thursday)

13.06.2017

(Tuesday)

28.06.2017

(Wednesday)

12.06.2017

(Monday)

14.06.2017

(Wednesda

y)

08.06.2017

(Thursday)

Lowest 12.24 13.89 16.11 26.22 12.26 19.28 7.94

Date (Day) 01.06.2017

(Thursday)

11.06.2017

(Sunday)

04.06.2017

(Sunday)

25.06.2017

(Sunday)

14.06.2017

(Wednesday)

25.06.2017

(Sunday)

06.06.2017

(Tuesday)

Average 21.48 21.46 21.56 35.89 18.52 30.39 17.54

July 2017

Highest 27.60 33.23 30.65 45.99 27.58 39.72 30.50

Date (Day) 01.07.2017

(Saturday)

19.07.2017

(Wednesday)

09.07.2017

(Sunday)

22.07.2017

(Saturday)

10.07.2017

(Monday)

29.07.2017

(Saturday)

31.07.2017

(Monday)

Lowest 13.27 17.84 16.85 30.54 10.94 12.29 11.09

Date (Day) 15.07.2017

(Saturday)

23.07.2017

(Sunday)

13.07.2017

(Thursday)

01.07.2017

(Saturday)

02.07.2017

(Sunday)

30.07.2017

(Sunday)

23.07.2017

(Sunday)

Average 21.01 24.60 22.13 36.94 18.35 28.91 17.63

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

46.10 Frequency of Operation of Southern Grid

Frequency of operation of the Southern Grid for the period under review is furnished below

please:

Month

Percentage of time when frequency (Hz) was

Month

Avg.

freq.

Less

than

49.5

49.5

to

49.7

49.7

to

49.9

49.9

to

50.0

50.0

to

50.05

50.05

to

50.20

More

than

50.20

Within

IEGC

range

49.9 to

50.05

February 2017 0.00 0.00 7.66 48.26 27.61 16.33 0.14 75.86 50.00

March 2017 0.00 0.01 11.52 49.30 24.71 14.40 0.06 74.02 49.99

April 2017 0.00 0.01 11.22 49.48 25.33 13.92 0.04 74.81 49.99

May 2017 0.00 0.03 11.90 47.56 25.78 14.62 0.11 73.33 49.99

June 2017 0.00 0.00 8.02 47.69 29.27 14.99 0.03 76.96 50.00

July 2017 0.00 0.01 8.26 48.04 29.33 14.36 0.00 77.37 50.00

During the period under review, caution / violation messages (Annexure-LVIII) were issued to

the constituents by SRLDC. Matter regarding overdrawal at low frequency by some

constituents is being regularly deliberated in the OCC forum. Utilities were requested to kindly

adhere to the Regulations in this regard.


47. CONGESTION RELATED ISSUES

47.1 In its 31st Meeting , SRPC had recommended to waive off the congestion charges from 77 to 80

blocks on 14th

Dec 2016, keeping in view the fact that applicable congestion notices had not been

received by some Generators / SLDC‟s (Congestion notice to be issued in line with provisions of

CERC approved Congestion Procedure).

47.2 Constituents who received any amount were requested to pay back to the pool, if not already done

so. SRPC Secretariat had issued the congestion waiver letter vide letter dated 17th

May 2017.

47.3 SRPC noted that the payments had already been settled.

48. REIMBURSEMENT OF SRPC EXPENDITURE

Statement showing net amount payable by Member Utilities of SRPC for the year 2017 -18, after

adjustment of surplus/deficit for the previous period is furnished in Annexure-LIX.

Members were kindly requested to ensure payment, wherever due.

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

49.1 Ministry of Power vide Order dated 17.03.2017 had allocated 540 MW of power from Ratnagiri Gas

and Power Private Limited (RGPPL) to Indian Railways. Allocation to SR States (out of 540 MW)

was as under:

State Nodal Railway Maximum load in MW after availability of

corridor between NEW Grid and SR*

Telangana SCR 50*

Tamil

Nadu

SR 100*

* date of effectiveness subject to availability of transmission corridor as per assessment of

CTU.

Subsequently MoP vide letter dated 18.05.2017 had allocated 35 MW of power to Karnataka

(SR).

CTU vide letter dated 20.04.2017 & 08.06.2017 had informed that ATC to SR from NEW

Grid has already been allocated to LTA/MTOA applicants for transfer of power to

constituent states of Southern Region including Telangana, Tamil Nadu & Karnataka.

Transfer of 150 +35 MW can be affected upon commissioning of upcoming Nizamabad-

Maheswaram 765 kV D/C line, which is likely to be commissioned by October 2017.

TSTRANSCO had convened a Meeting with Railways, SRLDC & SRPC on 28.04.2017.

TANTRANSCO vide letter dated 18.04.2017 had informed that the issue of consideration of

Open Access by Southern Railway as Deemed Licensee is sub-judice. At this stage the

Petition on the above matter is pending before Hon‟ble APTEL, New Delhi. Pending in

principle approval from TANGEDCO, permitting Open Access to Southern Railways as

Deemed Distribution Licensee for availing allocated power from RGPPL was not feasible.

TANTRANSCO had informed that APTEL Order was expected on 18.07.2017.

KPTCL and TANTRANSCO were once again requested to call for a Meeting with Railways

to address procedural & infrastructural issues.


49.2 KSEBL vide letter dated 14.08.2017 (refer Annexure-XXVI) had pointed out the following in

respect of Open Access request from Southern Railway, „it is stated that Southern Railways is

availing power supply for railway traction in Kerala State from 110 kV transmission network of

KSEBL at 11 supply points with contracted demand of 87 MVA. They have requested for NOC

and concurrence of SLDC for availing power as deemed distribution licensee. In this regard,

issues pertaining to operation and metering under connectivity and open access are to be

discussed/clarified. Power drawal in 2 phases is not desirable and has to be changed. It is also

stated that there is no CEA regulation for specification of meters used in 2 phase application‟.


MS, SRPC had informed that this issue was reportedly figuring in the meeting of PRAGATI

scheduled for 23.08.2017. Railways had stated that there were some issues in getting open

access from AP, TN & TS. Reply received from AP, TN & TS is given at Annexure-LX.

TANTRANSCO had informed that there was no Stay Order on the Hon‟ble CERC Order by

APTEL. Chief Secretary and Energy Secretary of TN Government would be attending the

PRAGATI Meeting and there were some apprehensions in this regard which would be

presented. There were issues in ensuring Standby power requirement since power would be

required to be procured to meet requirement especially during the outage of RGPPL units. As

deemed licensee Railways should have its own infrastructure. TN was agreeing for Open

Access to Railways as a Discom Consumer.

TSTRANSCO had informed that the metering requirements were yet to be complied by the

Railways. For 16 traction substations, estimate for providing the SEMs/SCADA had been

submitted to the Railways. Connected load of Railways in Telangana was around 250 MW

while open access was only being sought for 50 MW. How the simultaneous demand of

Railways would be met (likely to be higher than 50 MW) was an issue which needed to be

addressed. Deviations from the open access quantum were to be managed and thus a

mechanism needs to be in place.

KSEBL had informed that Railways had a connected load of 87 MVA and they had

requested for open access. The main issue was that they are drawing power in two phases and

also load is varying considerably. Presently, variations in the Railways load are being

managed by Discoms but how they are to be managed by the STU was an area of concern.

Open access quantum, whether average or maximum was also a factor which needs

consideration. Railways need to have balanced three phase supply and technically this was

possible. The transformers feeding Railway loads are subjected to unbalanced load, part

utilization, over heating etc which may lead to damage of these assets.

CEA Regulations stipulate balance load for bulk consumers availing supply at voltage level

at 33 kV and above and did not distinguish between Discoms and STU.

PCKL had stated that this was a techno-commercial issue. KPTCL stated that they had

approved LTA considering that Railways would remain consumer of Discoms.

NPC had stated that deemed licensee status had been granted to Railways under Section 14

by GoI and thus Railways is distribution licensee.

CTU had informed that the LTA could get operationalized from 01.10.2017. CTU clarified

that since there was GoI allocation to Railways, separate LTA application was not required.

GoI allocation is treated as LTA.

SRPC/SRLDC had reiterated that states needed to take necessary actions to implement the

MoP allocation and this were also being monitored under PRAGATI.

SRPC deliberations


49.4 MS, SRPC informed that the Railway allocation may get implemented from 01.10.2017 and thus

very little time was left to sort out the issues. This becomes critical since it is being monitored

under PRAGATI and CEA had also sought status of open access, Karnataka had granted open

access while status in respect of AP, TS & TN was furnished.

49.5 CMD, TSTRANSCO stated that they would comply with the allocation, Railways was likely the

third Distribution Licensee besides the two existing Discoms but there were certain issues which

were required to be addressed.

49.6 MD, KPTCL stated that KPTCL had given LTA on the assumption that Railways would remain

consumer of BSECOM (Traction S/S come under BESCOM). When RGPPL generation becomes

zero or reduces, they would continue to draw power and thus there had to be a standby agreement.

As they are first time cases, there are no clear cut guidelines in place. West Bengal had gone in

appeal before APTEL and TN had also joined in. Railways want to consume power without

standby arrangement and they want deemed licensee status without paying the stipulated charges.

This stand would be informed in the PRAGATI Meeting. When earlier Railway was being

granted STOA they were availing power for self consumption while basic definition of

Distribution Company was to distribute power to Consumers as per EA. Karnataka was watching

the outcome of appeal pending before APTEL.

49.8 CMD, KSEBL stated that what is of concern to KSEBL is that if Railways move out of their

network there could be other implications. As of now there were two models- some states had

approached Court while some were trying to retain Railways with some cross subsidy

consideration. Being a state where Railways is a major consumer and if such trend continues,

their profitability and sustainability in the long run would get eroded. If SERC is willing to give

some cross subsidy which would be spread over all consumers then the implications may not be

very severe. Also, there were issues involved if the generator supplying power to Railways goes

out for any reason.

49.9 CMD, APTRANSCO informed that Railways, APTRANSCO, DISCOMs, GoAP & Regulator

together had arrived at some consensus, in which the tariff had been reduced. With reduced tariff

a bilateral agreement had been signed for 2017-18. Railways had now agreed to continue this

agreement for another five years. Scenario has become competitive and power is available at

cheaper price. The best model may be to negotiate with the consumer and settle for mutual agreed

price and also bring Regulator into the picture. This has to be factored in ARR and Regulator also

had to take care of it in cross subsidy etc.

49.10 On query by KSEBL, CMD, APTRANSCO informed that Regulator had evinced keen interest on

the matter. The same concern of major consumers moving away (utility would be left with

subsidized consumers) was factored to agree for this model. Both DISCOM/TRANSCO favored


this model. Railways had weighed the options of exchange, UI, generator outage etc and were

confident that they could handle the standby/deviations.

49.11 CMD, KSEBL stated that the model could be shared with them for which APTRANSCO agreed.

49.12 CMD, TSTRANSCO stated that they were also negotiating with Railways and a meeting was held

with Chief Secretary along-with the Regulator. This issue was under consideration of the

Regulator.

49.13 MS, SRPC stated that MoP allocation would need to be implemented.

50. ADVANCE INTIMATION REGARDING FIRST TIME SYNCHRONIZATION OF

TRANSMISSION ELEMENTS

50.1 SRLDC had expressed concern that there is a huge gap between the guidelines and actual practice.

Last minute demands were being received for commissioning/charging of elements even though

Special Meetings and Workshops were conducted to make constituents aware of requirements and

importance of furnishing the information in the specified format. In number of cases, data

mismatch was observed after commissioning of the elements, which is not rectified by them on

priority after certification. The approved procedure needs to be followed.

50.2 SRLDC had revised and circulated this Procedure which is available on SRLDC website.


51. FREQUENT FAILURES OF TRANSMISSION LINE TOWER OF VOLTAGE LEVEL 220

KV AND ABOVE IN THE GRID

51.1 POSOCO vide letter dated 15.06.2017 (Annexure-LXI) had furnished the following:

Reliability of transmission lines is of utmost importance for safe and secure operation of

power system. Healthiness of substation equipment and transmission towers plays an

important role in ensuring the reliability of the transmission line.

Frequent incidents of tower collapse are being reported as a reason of transmission line

outage. A list of transmission line outages on account of transmission line tower collapse was

enclosed.

With trippings in a localized corridor, the inter-regional power transfer margins are hit and to

control the situation, ATC/TTC revision and power market curtailments have to be carried

out at RLDCs/NLDC level.

Early restoration of lines is equally important which gains importance from Regulation 5(b)

of CERC (Standards of Performance of inter-state transmission licenses) Regulations, 2012.

In the Regulation, it is mentioned that restoration time for tower after collapse by Emergency

Restoration System (ERS) of transmission line shall not exceed the 12 days. Also Central

Electricity Authority (Grid Standards) Regulations, 2010 where section 22 deals with

Emergency Restoration System states „Each transmission licensee shall have an

arrangement for restoration of transmission lines of 400 kV and above and strategic 220 kV

lines through the use of Emergency Restoration System in order to minimize the outage time

of the transmission lines in case of tower failures‟.

Some lines remained under prolonged outage for weeks/months together. Hon‟ble Central

Electricity Regulatory Commission (CERC) had taken suo-moto cognizance of such

trippings in the past and given certain directions vide order dated 14.06.2016 in petition


No.9/SM/2014 and 108/SM/2015.

51.2 It was observed that there were no lines of SR in the list of lines which remained under prolonged

outage for weeks/months together.


52. IMPLEMENTATION OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE

TRANSMISSION OF ELECTRICITY) REGULATIONS, 2017

52.1 Hon‟ble CERC had notified the Central Electricity Regulatory Commission (Communication

System for Inter State Transmission of Electricity), Regulations, 2017. These Regulations had

come into operation w.e.f 01st July 2017.


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

REGION

53.1 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 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) has been

carried out. The new OVR Gradings proposed to be adopted for these lines (along with study

results) have been circulated to all Constituents for modifications/ omissions/ comments, if any,

vide SRPC mail dated 06.04. After duly incorporating Constituents' comments, the final OVR

gradings to be adopted for 400 kV and 765 kV lines in the Southern Region have been issued vide

SRPC letter dated 17.04.2017 for implementation with immediate effect. The above OVR gradings

had also been kept in SRPC Website for easy reference.


54. APPRAISAL REPORT ON KSEBL‟S REVISED PSDF PROPOSAL FOR “RENOVATION &

UPGRADATION OF 220 KV SWITCHYARD EQUIPMENTS, AUTOMATIC GENERATION

CONTROL SYSTEMS OF MAJOR GENERATING STATIONS, AMR AND ASSOCIATED

WORKS”

54.1 KSEBL vide their letter dated 03.04.2017 had requested to arrange for an inspection by SRPC

Technical Team to appraise the works included in their proposal for PSDF funding, viz., “

Renovation & Upgradation of 220 kV Switchyard equipments, Automatic generation Control

Systems of major Generating Stations, AMR and associated works”. Subsequently, KSEBL vide

their mail dated 21.04.2017 intimated that they had revised the Detailed Project Report (DPR) as

per direction of the Techno-Economic Sub-group that held their Meeting on 30.03.2017 &

31.03.2017 at New Delhi, and requested to carry out the inspection as per revised DPR submitted

to PSDF Secretariat vide their letter dated 17.04.2017.

54.2 In this regard, an SRPC Committee consisting of Officials from SRPC, PGCIL (SRTS-II), and

TANTRANSCO had carried out the inspection of some of the KSEBL Stations during

27 – 30 April, 2017 with a view to appraise the orderliness of the works included in their revised

PSDF proposal (DPR).


54.3 Since the PSDF proposal of KSEBL consisted of two parts, viz., (i) Renovation & Upgradation

works at Idukki HEP, Sabarigiri HEP, Lower Periyar HEP & Sengulam HEP, and (ii) AMR works

spread across 34 generating stations of KSEBL, all four stations covered under first part, and a few

stations covered under second part had been inspected to ascertain the orderliness of the works

included.

54.4 Detailed technical appraisal of the Committee including financial propriety of various works

included was furnished to KSEBL vide SRPC letter dated 05.05.2017 for further necessary action.


55. STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY

RESOURCES INTO THE GRID

55.1 The proposal of SRPC had been approved by Monitoring Committee and Sanction Order had been

issued by MoP. Officers from state utilities, CEA, MoP, CERC, SRPC, POWERGRID, NTPC etc

participated in the training programme. The Study Programme was undertaken with the following

schedule:

Senior Level officials during 30.05.2017-10.06.2017- 11 Participants

Middle Level Batch I during 17.06.2017 to 30.06.2017- 16 Participants

Middle Level Batch II during 06.07.2017 to 15.07.2017 - 16 Participants

Middle Level Batch III between 27.07.2017 to 05.08.2017 – 18 Participants

55.2 The training was quite useful in understanding the challenges faced by Germany & Spain in RE

Integration and how they facilitated large scale RE Integration. It covered Grid, System Operation,

Regulatory, Policy, Transmission & Technical issues.


56. NON-ADHERENCE TO THE MAINTENANCE SCHEDULE SPECIFIC CASE OF

OVERHAULING OF TALCHER STAGE II UNIT No.4

56.1 KSEBL vide letter dated 14.08.2017 (refer Annexure-XXVI) had stated that Overhaul scheduling

of Unit 4 of Talcher-II was altered from the schedule finalized in the Annual Outage Plan.

Subsequently, NTPC had also not adhered to the revised schedule agreed in the 132nd

Meeting of

OCC. In respect of Talcher-II Unit outage, the impact on the inter-regional corridor is high and any

change in ATC affected market operation also. It had been stated that uncertainty in the planned

maintenance works was a matter of serious concern. Another point of concern is the absence of

proper representation in the OCC Meeting where all such decisions are taken.


KSEBL had reiterated that non availability of Talcher-II affected them since they had a major

share in Talcher-II. Besides the balance ATC available is also affected by the DC/unit

availability at Talcher-II.

NTPC had informed that major overhaul was planned at U-4 of Talcher-II; deployment of tower

crane had lot of issues since it was a running plant. Such delay would be avoided in future and

suitable care would be taken. Necessary instructions had already been communicated to the

stations to adhere to the maintenance schedule.


NTPC had assured of regular participation in the OCC Meetings in future.


57. OUTSTANDING DUES FROM TSDISCOMS TO APGENCO

57.1 APGENCO vide letter dated 16.08.2017 (Annexure-LXII) had stated that outstanding dues of Rs

3943.91 crores were due to them from TSDISCOMs as on 03.08.2017.


APGENCO had stated that they were continuously requesting for payment of outstanding dues

without linking the same with demerger issue. Demerger issues could be settled in the identified

Committee. M/s Singareni had stopped coal supply to APGENCO from 26.07.2017 onwards due

to non-payment of earlier dues to the tune of Rs 1,437 crores. Coal stock position in APGENCO

stations had dropped significantly. After repeated requests, coal supply had been resumed

partially.

TSTRANSCO had stated that the issue could be deliberated bilaterally.

It was noted that the issue could be deliberated further in the SRPC Meeting.

SRPC deliberations

57.3 CMD, APTRANCO stated that the issue would be discussed bilaterally and not in this forum. Only

because there was some precedence, the matter had been brought to the attention of this forum

58. URS ALLOCATION TO NON-BENEFICIARY

58.1 In the 133rd

Meeting of OCC held on July 2017, it was suggested that though a few states are not

having share in some of the CGS in SR, they could be allowed to avail the URS power. It was

suggested that this matter may also be discussed in the Commercial Sub-committee Meeting.

Subsequently, this matter was discussed in the 35th

Meeting of Commercial Sub-committee held on

08th

August 2017. After deliberations, all constituents had agreed to this proposal, in principle. It was

recommended that this matter be discussed further in the ensuing TCC/SRPC Meetings.

58.2 TCC had recommended that URS could also be reallocated to the non-beneficiaries in Southern

Region. Chairperson, SRPC would be kindly requested to take up this matter with MoP.

58.3 SRPC approved the same.

59. CONCLUSION

Chairperson, SRPC expressed great pleasure in thanking CMD, KSEBL, for the outstanding

arrangements. He also thanked all the Members for the exhaustive deliberations both in TCC and

SRPC Meetings. He thanked one and all for attending the Meeting and also making it successful. He

also hoped that the Overarching Agreement would be concluded very soon.

60. DATE & VENUE OF THE NEXT MEETING OF SRPC

NLC kindly consented to host the 33rd

Meeting of SRPC. The date and venue would be

communicated in due course.

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