southern regional power committee - … of line differential protection (ldp) in nellore and...
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 1
CONTENTS
1. INTRODUCTION .............................................................................................................................................. 3
2. CONFIRMATION OF THE MINUTES OF THE 30th MEETING OF TCC ............................................................... 7
3. OPERATION OF HYDRO POWER PROJECTS IN PEAKING MODE ..................................................................... 7
4. MEMBERSHIP TO RPC ................................................................................................................................... 11
5. PREPARATION FOR MEETING REVISED ENVIRONMENT NORMS AS PER ENVIRONMENT (PROTECTION)
AMENDMENT RULES, 2015 .......................................................................................................................... 11
6. RELIABLE COMMUNICATION SCHEME UNDER CENTRAL SECTOR FOR SOUTHERN REGION ....................... 13
7. TECHNICAL COMMITTEE FOR IMPLEMENTATION OF FRAMEWORK ON RENEWABLE AT STATE LEVEL -FOR13
8. TECHNICAL COMMITTEE CONSTITUTED BY CEA .......................................................................................... 14
9. OPTIMUM HARNESSING OF RE IN SOUTHERN REGION ............................................................................... 14
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 ............. 32
14. REQUEST TO ISSUE CERTIFICATE FOR CLAIMING ADDITIONAL ROE AS PER CERC GUIDELINES IN RESPECT OF
TRANSMISSION ELEMENTS ASSOCIATED WITH THE FOLLOWING SYSTEMS ............................................... 39
15. NEW PROJECTS OF NTPC, NLC, NPCIL, JOINT VENTURE & UMPP ................................................................ 39
16. NEW PROJECTS OF STATE SECTOR & IPP ..................................................................................................... 42
17. ROADMAP TO OPERATIONALISE RESERVES IN THE COUNTRY .................................................................... 43
18. INCLUSION OF DRAWAL OF MAHE IN REA ................................................................................................... 45
19. ISSUES IN RESPECT OF NPCIL ........................................................................................................................ 45
20. COMMUNICATION REQUIREMENT DURING NATURAL DISASTERS ............................................................. 48
21. STATUS OF GENERATION IN ISGS ................................................................................................................. 48
22. REVIEW OF ULDC / SCADA/COMMUNICATION ............................................................................................ 49
23. URTDSM (PMU) PROJECT IN SOUTHERN REGION ........................................................................................ 51
24. SCHEDULING OF WIND & SOLAR GENERATING PROJECTS HAVING CAPACITY OF 500 MW AND ABOVE ... 53
25. TTC/ATC ........................................................................................................................................................ 54
26. METHODOLOGY FOR CERTIFICATION OF INTRA-STATE TRANSMISSION LINE ............................................. 56
27. EMERGENCY RESTORATION SYSTEM (ERS) .................................................................................................. 56
28. PROGRESS OF BUS/LINE REACTORS TO BE COMMISSIONED IN SR ............................................................. 58
29. OUTSTANDING DUES BETWEEN SOUTHERN AND WESTERN REGIONS ....................................................... 62
30. NON-AVAILING OF OCC APPROVED SHUTDOWN ........................................................................................ 63
31. STATUS OF PHASE I AND PHASE II OF PROTECTION AUDIT RECOMMENDATIONS ...................................... 64
32. SPARE ICT AND REACTOR PLACEMENT AND USAGE PROCEDURE ............................................................... 65
33. IEGC RELATED ISSUES REQUIRING ATTENTION/ACTION .............................................................................. 66
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34. IMPLEMENTATION OF PROTECTION SUITE / PROTECTION MANAGEMENT SYSTEM (PMS) FOR SOUTHERN
REGION ......................................................................................................................................................... 81
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 ............. 83
36. PROTECTION AUDIT OF SUBSTATIONS IN SOUTHERN REGION CONDUCTED DURING MARCH – AUGUST,
2017 .............................................................................................................................................................. 84
37. AUTO-RECLOSURE IMPLEMENTATION ON ALL 220 KV & ABOVE TRANSMISSION LINES OF SOUTHERN
REGION ......................................................................................................................................................... 84
38. IMPLEMENTATION OF LINE DIFFERENTIAL PROTECTION (LDP) IN NELLORE AND SIMHADIRI COMPLEXES 86
39. PATROLLING / MAINTENANCE OF CRITICAL LINES AND SUBSTATIONS ....................................................... 87
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 ....................................................................................... 88
41. PENDING IMPLEMENTATION OF RECOMMENDATIONS OF PROTECTION COORDINATION SUB-COMMITTEE
(PCSC) OF SRPC ............................................................................................................................................. 88
42. COMMERCIAL COMMITTEE ISSUES .............................................................................................................. 89
43. MONITORING OF SCHEMES FUNDED FROM PSDF ....................................................................................... 90
44. SCHEDULING OF KAMUTHI SOLAR PARK ...................................................................................................... 90
45. AUGMENTATION OF TALCHER-II TRANSMISSION SYSTEM .......................................................................... 91
46. GRID OPERATION ......................................................................................................................................... 92
47. CONGESTION RELATED ISSUES ................................................................................................................... 100
48. REIMBURSEMENT OF SRPC EXPENDITURE ................................................................................................. 100
49. STATE-WISE ALLOCATION OF 540 MW POWER FROM RGPPL TO RAILWAYS............................................ 100
50. ADVANCE INTIMATION REGARDING FIRST TIME SYNCHRONIZATION OF TRANSMISSION ELEMENTS ..... 102
51. FREQUENT FAILURES OF TRANSMISSION LINE TOWER OF VOLTAGE LEVEL 220 KV AND ABOVE IN THE GRID
102
52. IMPLEMENTATION OF CERC (COMMUNICATION SYSTEM FOR INTER-STATE TRANSMISSION OF
ELECTRICITY) REGULATIONS, 2017 ............................................................................................................. 103
53. OVR GRADING OF 400 KV AND 765 KV TRANSMISSION LINES OF SOUTHERN REGION ............................ 103
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” .............................................................................................. 103
55. STUDY PROGRAMME ON THE INTEGRATION OF RENEWABLE ENERGY RESOURCES INTO THE GRID ....... 104
56. NON-ADHERENCE TO THE MAINTENANCE SCHEDULE SPECIFIC CASE OF OVERHAULING OF TALCHER STAGE
II UNIT No.4 ................................................................................................................................................ 104
57. OUTSTANDING DUES FROM TSDISCOMS TO APGENCO ............................................................................ 104
58. URS ALLOCATION TO NON-BENEFICIARY ................................................................................................... 105
59. CONCLUSION .............................................................................................................................................. 105
60. DATE & VENUE OF THE NEXT TCC MEETING .............................................................................................. 105
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SOUTHERN REGIONAL POWER COMMITTEE
BENGALURU
MINUTES OF THE 31st MEETING OF TCC HELD ON 21.08.2017 AT
THIRUVANANTHAPURAM
1. INTRODUCTION
1.1 The 31st Meeting of the Technical Coordination Committee (TCC) of SRPC was held on 21
st
August 2017 at Thiruvananthapuram. The list of participants is given at Annexure-I.
1.2 Team KSEBL welcomed the esteemed Delegates of the 31st TCC & 32
nd SRPC Meetings to „Gods
Own Country‟. The Meeting was being hosted in Thiruvananthapuram, with Arabian Sea on the
west and Tamil Nadu on the east and named after „Anantha Padmanabhan‟. The city is home to
many temples with a long seashore and also other historic monuments. The backwaters and rich
cultural heritage makes the city a much sought after destination.
1.3 Dr K Ellangovan, CMD, KSEBL stated that it was a proud privilege to extend a warm welcome to
Members of TCC, Special Invitees and other Participants to the 31st TCC & 32
nd SRPC Meetings
being conducted in this beautiful city of Thiruvananthapuram the abode of Lord Padmanabha. It
gave immense pleasure to host this event and welcome delegates and invitees for the two day long
deliberations. The city was hosting SRPC Meeting for the third time. He welcomed Shri G Narsing
Rao, Director (P&GO), TSTRANSCO & Chairperson TCC and Shri S R Bhat, Member Secretary,
SRPC and all esteemed colleagues to the event. Members had assembled after about 6 months to
discuss several operational, commercial and policy matters. He hoped that the Members of the
august gathering would provide valuable opinion on the Agenda placed before the Committee for
deliberations and decisions. GoI‟s mandate of 100 % electrification and 24 x 7 power supply to all
was to be met for which a robust and constraint free network was essential. He shared with the
gathering KSEBL‟s happiness in achieving 100 % electrification in the state of Kerala. The state
had been declared fully electrified on 29th
May 2017 by the Hon‟ble Chief Minister at Kozhikode.
It had been a huge task to extend electricity to many remote villages in the Western Ghats. In many
places in order to overcome forest issues, underground cables as long as 18 km had been laid. He
placed on record appreciation of his colleagues in achieving this great milestone. CMD observed
that unprecedented increase in renewable portfolio in the region was having its own share of issues
and thus its integration would be a highly deliberated matter. The current drought scenario in the
region has constrained the hydro reserves, which is very critical for balancing variability of
renewables. Another major area of concern was the issue faced by thermal power plants in meeting
the deadline for revised environment norms as per the Environmental Protection Amendment
Rules 2015. Power sector was embracing new technologies such as synchro-phasor technology,
wide area monitoring system etc in the Smart Grid era. Real time monitoring of renewables is
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highly essential for securing grid safety. Effective communication being heart of the above system,
proposal for establishment of new FO links would go a long way in strengthening existing
communication system. He again extended his warm welcome to each and every delegate and
wished the Meeting a grand success.
1.4 A short documentary on KSEBL and Kerala was presented which highlighted:
Kerala was a fully electrified state with highest rate of domestic electrification and one of
lowest AT&C losses in the country.
KSEBL has been energizing the state of Kerala since 1957.
Forest covers 29 % of the state and constraints of developing projects needed no over
emphasis. This constraint was the beauty of the state.
Kerala‟s installed capacity has grown over twenty six times in the last six decades. From just
one Hydel project in 1940, the infrastructure has brought in twenty seven Hydel projects
including Idukki Hydro Electric Project, which is India‟s only and Asia‟s second largest Arc
Dam.
KSEBL is moving ahead with 11 ongoing projects capable of generating 500 MW. 37 others
are in pipeline aiming for 1,700 MW mostly exploring renewable and non -conventional
energy options.
Per capita consumption had increased from 19 units in 1957 to 502 units presently registering
a current annual growth rate of 7 %.
KSEBL with over 10,000 ckm of transmission and 2.7 lakh ckm of distribution lines has
diversified and expanded its activities to provide many online services. The utility has
developed its own software for billing, human resource activities etc and information systems
to handle a self-managed meter data management.
In contrast to national scenario, almost 80 % of 1.25 Crore customers of KSEBL are
domestic which contribute to 30% of the total revenue. The industrial consumption comes to
30 % while commercial connections amount to 15 %. Unlike other states, HT & EHT
category is only 0.04 % of the total consumer base but contribute to 34% of the revenue.
Kerala has always kept the tariff low enough to serve its domestic sector enabling KSEBL to
win societies unlimited trust.
Growth in consumer base and sky rocketing demand for power have resulted in Kerala‟s
increased dependence for import of power and Kerala‟s internal generation contributes about
30 % of daily requirement while rest is managed through imports.
KSEBL has been making strategic shift in power purchase by depending more on
Independent Power Projects. The import prospects are at times dampened on account of
limitations in transmission lines which is an issue being strongly addressed by KSEBL.
With a keen eye on future, KSEBL is working on alternatives and projects that will narrow
down the demand gap of 800 MW which may shoot up to 2,700 MW by 2022 when system
demand could be around 6,000 MW.
System Operation Wing was able to manage the grid without load shedding since June 2013
through meticulous planning and effective management.
In the transmission sector, works on the TransGrid had been so geared to tap potential of the
first HVDC link between Pugalur & Madakathara.
KSEBL has put considerable efforts to ensure last mile connectivity be it marshy land, forest
or a hill.
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1.5 Shri S R Bhat, Member Secretary, SRPC welcomed the TCC Members and all the delegates to the
Meeting. He specially thanked CMD, KSEBL and said that it was gracious on his part to spare
time and inaugurate the TCC Meeting. He thanked CMD, KSEBL and the entire team for the
wonderful arrangements made. He welcomed Shri G Narsing Rao, Director (P&GO),
TSTRANSCO and Chairperson TCC and requested him to Chair the Meeting.
1.6 Shri G Narsing Rao, Director (P&GO), TSTRANSCO & Chairperson TCC expressed immense
pleasure in welcoming one and all and said that he was honored to Chair the TCC. He
congratulated the KSEBL Management and its team for the splendid arrangements made in
organizing the Meeting. He appraised the forum of the developments in power sector in
Telangana:
Telangana was bifurcated from united AP on 02.06.2014.
At time of bifurcation there was load shedding of 4 hours in cities, 6 hours in municipalities
& more than 8 hours in mandal headquarters & villages. There was power holiday in
industrial sector for two days in a week. Power supply to agricultural sector was for 6 hours a
day.
Within 6 months of state formation, a comfortable power supply position was achieved with
the support of State Government under the able guidance of CMD TSRANSCO &
TSGENCO and good coordination of all the employees.
Presently there are no power cuts for any category of consumers in the state. 9 hours power
was being extended to the agricultural sector.
Installed capacity had increased from 6,574 MW to 13,645 MW. Solar had increased from 61
MW to 2,092 MW while wind had increased from 0 to 100.8 MW since formation.
217 EHT SS & 16,374 ckm of EHV lines had increased to 289 EHT SS & 20,640 ckm EHV
lines. Transformation capacity had been enhanced from 30,439 MVA to 47,784 MVA
along-with strengthening of distribution network.
Farmers of 10 districts out of 31 districts are being provided 24 hours of quality and reliable
power supply and same would be extended to the remaining districts in a short period.
Peak demand of 9,397 MW had been met on 07.08.2017. Maximum energy of 196.17 MU
was supplied on 03.08.2017.
Per capita consumption of 1,390 kwh was more than national average of around 1,000 kwh.
An in-house „Telangana Vidyuth Shakti‟ App had been developed for monitoring real time
power situation within the state which provides current day and previous day demand along-
with other details.
On grid side, he noted that Southern Region has been a forerunner in adhering to grid discipline
by taking proactive measures. The recently concluded Overarching Agreement for managing
RE generation in the Region by sharing surplus energy exemplified the same. SR has RE of
around 22 GW which is targeted to reach 60 GW by 2022 out of the total target of 175 GW.
Addition of such huge RE generation poses major challenges in grid management on account of
unpredictable nature of RE generation. Another issue in harnessing this huge capacity addition
is timely execution of evacuation schemes and downstream networks to bring power to the
needy. He urged all constituent members to bestow their personal attention in planning and
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executing evacuation as well as downstream network. This would also help in better utilization
of Inter Regional links for importing and exporting power as per requirement. He urged the
Members of TCC to deliberate on Agenda Items in detail and reach at consensus to address
issues being faced by SR and also maintain Regional Grid with utmost discipline through
mutual cooperation and collaboration.
1.7 TCC welcomed the following new Members:
Shri D Ravi, SE-I, Electricity Department Puducherry
Shri Pardeep Jindal, Chief Engineer, NPC,CEA
Shri P K Mohapatra, Regional ED, SRHQ, NTPC
Shri M Prabhgar, CEO, NTPL
Shri Sabyasachi Mukharjee, Sr VP, O & M, HNPCL
TCC placed on record excellent services rendered by the following outgoing Members:
Shri U Vidyasagar, CGM, TSSPDCL
Shri K Mathivanan SE-I, Electricity Department Puducherry
Shri P V V Satyanarayana, CGM, APEPDCL
Shri B C Mallick, Chief Engineer, NPC,CEA
Shri V B Fadnavis, Regional ED, NTPC
Shri A R Neelakanta Pillai, CEO, NTPL
1.8 Member Secretary, SRPC thanked Smt P Vijayakumari Director, (T&SO), KSEBL and her team
for the excellent arrangements for the Meeting. He especially welcomed Shri Pardeep Jindal, Chief
Engineer, CEA and added that his presence would certainly add much value to the deliberations.
He also welcomed Shri G Anbunesan and informed the forum that he had been elevated as General
Manager, SRLDC. He hoped that SRLDC would continue to grow under his able leadership. He
appraised about the following highlights in the Region:
Merit Order Dispatch (MOD) portal had been launched by Hon‟ble Union Minister of Power.
Cooperation of all states in making it operational was acknowledged.
In Tamil Nadu, on 04th
August 2017, record wind generation of 102 MU was evacuated.
NTPC had achieved COD of Kudgi Unit -1 on 31st July 2017.
NTPC had crossed 50 GW of Installed Capacity in the Country.
KPCL had achieved record generation last year in 2016 -17.
SRLDC had conducted a number of capacity building and other workshops.
Under the able guidance of Chairperson, SRPC, the Overarching Agreement had been
signed by 4 out of 5 states on 17th
August 2017.
Contribution/cooperation of all constituents in smooth grid operation.
Study Programme on Renewables had been successfully coordinated by SRPC Secretariat.
Four batches of officials from MOP, CEA, CERC, Constituent States, PGCIL, NTPC, NLC,
NLDC, SRLDC & SRPC Secretariat had gained experience from this training programme.
Regarding Protection Management System (PMS), the LOA had been recently placed; all SR
states had been involved in detailed manner.
SRTS-I, PGCIL contribution in bringing Nizamabad-Maheswaram which with other
elements could help increase TTC to SR.
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SRTS-II, PGCIL for being best performing region in PGCIL, assessed on a number of
parameters.
He also pointed out the system operation challenge, since the current hydro position was around
1,700 MU less than that same time last year.
2. CONFIRMATION OF THE MINUTES OF THE 30th
MEETING OF TCC
2.1 Minutes of the 30th
Meeting of TCC held on 24th
February 2017 at Bengaluru was circulated vide
letter dated 12th
April 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 generation 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‟.
TCC deliberations
3.3 MS, SRPC outlined following background of this issue:
Report suggested that around two thousand MW of additional peak hour generation from
hydro is possible.
Report talks about operational intervention, policy, regulatory framework, ancillary services
from hydro, dispatch to factor demand pattern, electricity prices, valuing flexibility through
incentive etc
Sub Committee had been set up under Chairmanship of Chairperson, CEA to study and
recommend individual hydro stations which could be operated to achieve peak load. There
had been couple of Meetings held in this regard. The matter was to be discussed in the
Monthly Meetings of OCC for operational planning for the month and also analysis of
previous month.
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Issue had been discussed in detail in the 134th
Meeting of OCC held at Neyveli on 11th
August 2017 (Summary given as Annexure-IV). Gist of the deliberations was that it cannot
be summarized that hydro is always must run especially since scheduling and planning for
storage type stations is for the entire water cycle year. Hydro is used for other functions such
as RE balancing/intermittency etc. Storage content naturally also needs to be taken into
account. There was no static operating principle in this regard. Since hydro operation was to
be dynamic and also dependent on storage position, averages may not necessarily work.
Since Dispatch tends to trend electricity market prices, at times, market prices may be more
attractive. In such a scenario, hydro generation could be brought down. Issue regarding
coincidence of National Peak and individual State Peak needed to be examined. States being
individual Control Area also utilized hydro for internal load generation balance and to meet
RE intermittency. Value of hydro power is to be based on price and not on cost, Karnataka
flexed its hydro generation and maximum utilization during the water year typically was
during the period January to April.
3.4 The following were the views of the Entities:
SRLDC/NLDC
Presentation made by SRLDC/NLDC is given at Annexure-V.
Entire idea of report was to identify constraints presently being faced in Hydro, hydro
generation optimization, defining flexibility, parameters of flexibility, hydro generation
pattern, flexibility – peaking, ramping etc, valuing of hydro, importance of pump storage,
constraints in hydro generation - generic issues on all India basis, tariff structure- based on
questionnaire circulated to all states, present CERC tariff structure, scheduling and
dispatch- CERC mechanism, International hydro experience and practice and
recommendations.
Observations- 25 % of time, peaking requirement was there where hydro could be
maximized. 25 % of time, there is the off peak where pumping could be considered, typical
day – ramping and flexibility requirements exhibited on national and region wise also.
Constraint- silt, coordination in common basin, transmission evacuation, grid events causing
hydro station outages, coordinated outage planning to avoid spillage & social obligations.
Scheduling- centralized scheduling practices in NR, ER & NER, cross border trading-
Chukha & Tala and Best Fit Method- Sardar Sarovar.
Flexibility- Peaking, Ramping & Capacity Utilization Factor. Multi Part Tariff- CGS
performed better during peaks. Hydro support of 30 GW in peak & 18-20 MW in off peak
against installed capacity of 45 GW. 87 stations are having Black Start facility while 25
stations out of 150 are having synchronous condenser facility
Value of water – in monsoon to avoid spill it needs to be used.
Correlation- Higher correlation in lean hydro season, to achieve the peak 79 % Installed
Capacity met to achieve the peak with minimum of 9 %, average is around 33 %, 4 GW -34
GW has been the variation.
Hydro duration analysis was presented, the hydro generation of NR ISGS was presented-
being used to meet peaks & overload capacity was also being utilized.
NLDC stated that after meeting all the constraints of the state, balance could be utilized
during peak. During 19:00 hrs to 19:30 hrs, the frequency was going low.
Incentive should be for hydro providing peaking support and tariff structure aligned to meet
the objectives.
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Report recommends Multi part tariff for better utilization of hydro resources.
National Peak was a matter of concern - on 17.08.2017, highest peak of 161 GW had been
met, 210 MW/minute was ramp requirement and had to be contributed by all sources. Liquid
fuel was scheduled to meet the peak since numbers of units were under RSD.
In 3rd
Committee Meeting, generators had been identified throughout the country which
could be optimized to meet peak demand.
TSTRANSCO
From the presentation it appeared that hydro support is required to meet the National Peak
Demand not having direct relation to state operation.
State hydro operation depended mainly on irrigation quotas and its own load generation
balance. Within this quota, optimum scheduling is carried out.
States follow Control Area concept and available resources are used in economic manner for
state‟s LGB. This cannot thus be extended to other Control Areas and for National Peak.
Dispatch based on national level peak, ramp rates etc may be considered only with a proper
market mechanism in place.
KSEBL
KSEBL have serious reservations on this Report.
States‟ view/input should have been properly reflected in the Report.
Utilization is based on the rainfall, period of rain/inflow etc.
Scheduling is under domain of SLDC and hence cannot be as per NLDC requirement.
This Report has not been shared in full shape and SLDCs have not been consulted
appropriately.
Some of the generators are only for generation and not linked to irrigation. There is full
flexibility in scheduling them and they are scheduled to meet the LGB of the state.
Deficits due to curtailment on transmission is met by hydro.
Merit Order for hydro is not the cost of generation but it is price of generation. Price is the
cost of costliest replaced energy in the entire year.
During monsoon, winter or even summer, cost of power during peak is less than other period
- so it makes sense to replace the costliest generation. It happens several times and can be
verified from IEX clearance prices.
To meet demand, some reserve needs to be maintained and it is always kept in hydro in
KSEBL. Generally they keep 100 MW reserve in hydro to meet a demand of around 4,000
MW. All other power is contracted/scheduled and has limited flexibility.
Two major stations Idukki & Kakayam have been identified to provide peaking support. To
conserve/optimize generation only 200-250 MW is being generated against the Installed
capacity of 780 MW. One Machine is under renovation while other is under annual
maintenance. Water is also being conserved for next summer. 500 MW of generation now
would lead to no water/generation during the peak month of March. Water is also required
for irrigation/drinking water requirements.
Generation is planned for the entire water cycle year. At times, for reactive support machines
need to be kept on bars.
Cost of market power has already been factored in the hydro optimization program.
SERC was fixing the tariff and they need to be convinced that hydro is being used for benefit
of the state. Hydro was being optimized to keep the tariff to minimum possible in the state.
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In case suitable market mechanism/incentive scheme is in place, harnessing of state hydro
can be considered since then, the whole concept of hydro optimization would get altered.
TANTRANSCO
This was the 2nd
consecutive year of monsoon failure. Hydro storage was only 15-20 %
which was required to meet the State‟s LGB.
Hydro practice of NE/NR should not be compared with the practice of SR. Peak study based
on last one year data also cannot be conclusive.
Hydro was also required to meet RE penetration of more than 6,000 MW.
APTRANSCO
Water is planned up to next rainy season.
Hydro generation is also based on irrigation and drinking water requirements.
Any incentive scheme may take away the grid security reserve.
KPTCL
Hydro is utilized as spinning reserve to meet peak demand.
They conserve hydro till December and maximize it during Jan to April to meet the peak
demand, exams, summer agricultural crops. There is additional requirement of around 15
MU/day during that period and cost of energy is also higher.
They need the hydro energy for themselves and cannot be spared for others.
Grid security was a major issue and hydro is meticulously planned for the water cycle year.
Hydro is used for meeting peak, deviations; fall in frequency, forced outage of state thermal
generation, sudden withdrawal of wind etc.
Even without RE, hydro optimization was a struggle. Sudden withdrawal of wind and solar
can only be met through hydro modulation. In July 2nd
week, on account of wind
withdrawal, about 1,000 MW of hydro was generated to bridge the deficit.
Only 42 % storage was available which works out to 1,900 MU. This translates to about 6
MU/day for balance 317 days of water cycle. All units at Sharavathy to meet the peak would
consume about 4 MU/day. Only 4 units are kept to bars at Sharavathy to have margins in
both directions. With good RE or fall in demand, only 2 MU/day is consumed.
PCKL
There was around 3,000 - 4,000 MW of stranded gas stations which can be used in RE
balancing. MS, SRPC stated that this aspect had been discussed by the Committee under the
Chairmanship of Member (Planning), CEA which is also covered subsequently in the
Agenda. There could be some policy initiatives in this regard.
NPC
It is a good Report in terms of analysis.
Associating the Report with FOLD may need to be ascertained since many SLDCs are
claiming that they were not consulted in a detailed manner.
As per the Report there could be 6,000 MW during peaking, while as per analysis of CEA
about 2,000 MW was the likely benefit.
3.5 The following was summarized in this regard:
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.
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NLDC stated that the feedback of these Meetings would be considered.
Suitable Market mechanism/incentive scheme needs to be in place for the purpose of any
hydro optimization.
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.
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.
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.
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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.
TCC deliberations
5.6 Director (T), APGENCO 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 the 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.
5.7 Director (T), TSGENCO expressed concern over space constraints for FGD installation in some of
the plants and over the huge expense to the GENCOs and consequent implications on tariff.
5.8 NLC informed that they had appointed M/s Mecon as Consultant and the measurements had been
taken at site. Based on the results, the type of FGD etc would be suggested by the Consultant. NLC
was seriously pursuing this matter and a decision would be taken after the Consultant‟s report is
made available.
5.9 Generators were 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.
5.10 After deliberations, TCC recommended that Chairperson, SRPC may be kindly requested to take up
the issue of funding (PSDF/any other fund) with Ministry of Power once again, for meeting the
environment norms.
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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 TCC 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.
TCC deliberations
7.3 MS, SRPC informed that the Sub Group had submitted certain recommendations which also
included the 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 present available products.
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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.
TCC deliberations
8.2 MS, SRPC informed that in the Committee Meeting, a new concept of net DSM had been discussed
through which a state would get insulated from vagaries of RE. DSM of the Control Area would 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.
TCC deliberations
9.1.3 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.
9.1.4 MS, SRPC informed that the Overarching Agreement had been signed between APPCC,
TSDISCOMs & KSEBL on 17th
August 2017. He thanked the utilities for their kind cooperation in
this regard.
9.1.5 Chairperson, TCC suggested that PCKL & TANGEDCO may also sign the Agreement especially
since there was no compulsion what so ever to go for any trade.
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9.1.6 PCKL stated that they would communicate their views in the SRPC Meeting.
9.1.7 Director (O), TANTRANSCO raised certain apprehensions on settling at MCP rate which may be
lower than the RE purchase cost. TN was however willing to transact power under Swap
arrangements under mutually agreed conditions.
9.1.8 It was pointed out that there had been instances of simultaneous underdrawal and overdrawal by
SR constituents and sustained underdrawal by TN. There were contingency situations in which
other states were requiring power and also other options of STOA were always open to TN. RE
attributes could remain with TN. This entire concept had been conceived for RE balancing for TN.
In view of this TN was kindly requested to also sign the Agreement.
9.1.9 TANGEDCO stated that they would consider signing the Agreement under Swap with mutually
agreed rates for the residual energy.
9.1.10 In respect of SAMAST implementation, the following was noted:
APTRANSCO 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 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 lower
funds are approved, it may not encourage entities to take up the project in a time bound
manner.
KPTCL informed that they were preparing the DPR and they had also sent a Committee to
Gujarat and MP to study their proposals. The DPR would be finalized by end of the month.
MS, SRPC noted that this system was required for Intra-state ABT, settlement, RE deviations
etc. A holistic view thus needs to be adopted in this regard.
9.1.11 TCC urged the 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 the states on a priority basis.
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 TCC suggested constituents to consider the possibility of using lift irrigation loads as demand
response.
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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 operation 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.
TCC deliberations
9.3.2 Director, TSGENCO 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. The OEM M/s Hitachi had visited in July 2017 and approved operation
of N‟Sagar units in pump mode. Once the lift irrigation scheme gets elevated and with sufficient
available water, units can be operated in pump mode.
9.3.3 TSGENCO was suggested to kindly take up issues with regard to Srisailam / N‟Sagar pump mode
operation, which may require attention of CEA.
9.4 Pump Storage Plants
9.4.1 A Meeting was convened by CEA on 28.06.2017 (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)
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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).
TCC deliberations
9.4.2 TCC suggested the constituents to follow the pumping proposals 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 was 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.
9.6 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.
TCC deliberations
9.6.3 Constituents were kindly requested to consider this aspect for better reserve planning, balancing etc.
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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 all the 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
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 19
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.
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 20
10.8 The following was 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 was required.
Constituents expressed concern regarding real time data from Roof Top Solar with the
present level of infrastructure.
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.
11.3 The following had been noted in earlier Meetings:
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.
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 21
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.
11.7 The following was noted in the TCC Meeting:
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. About 1,200 MW TTC increase was
expected from 1.10.2017.
b) WR-SR 6000 MW HVDC Bipole Link
[Raigarh (Chhatisgarh) - Pugalur-
Trichur (TN/KER)]
Apr‟ 2020
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 22
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.
12.1.3 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:
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 23
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
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
kV Yelahanka
PGCIL 31st TCC :
Oct 2017
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.
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 24
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.‟
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
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 25
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.
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 26
Yermarus TPS -
Bellary PS 400 kV
D/C QM
(400 kV MC (5.138
Kms) and 400 kV D/C
line(137.355 Km) =
142.493 Kms)
285
Expecte
d by
Aug‟17
213 ckm out of 285
completed
Bellary PS -
C.N.Hally 400 kV
D/C line QM
360
29
th TCC update:
Part of the work from
Rampura-Jagalur 65
kM had been
awarded.
Bellary PS to
Madhugiri (PGCIL)
a) Madhugiri to
Rampura limits):
400 kV D/C QM
Bellary PS to
Rampura limits
(KelaginaKanavi)
188.74
43.018
364
86
22-12-
16
24-04-
17
Comple
ted
Comple
ted
31st TCC :
Testing under
progress. Would be
commissioned
shortly.
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
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Minutes of the 31st Meeting of TCC held on 21.08.2017 Page 27
Status of upcoming links having impact on S1-S2
400 kV Somanahalli-
Dharmapuri PS
243 PGCIL Jun‟15 31st
TCC:
Decem
ber
2017
Severe RoW
problems being faced
in Karnataka.
Compensation issues
under progress.
PGCIL had informed that regarding 400 kV Dharmapuri - Somanahalli line, DC
(Urban) had ordered compensation of 100 % of fair value for tower footing and 55 %
for line corridor. With this, cost of 30 kM line was working out to as high as Rs 90
crore. It would take around two months to complete the work once ROW issues are
resolved.
400 kV Mangalore
(UPCL ) -Kasargode-
Kozhikode
TBCB 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 expressed concern and stated that the line needs to be expedited.
CE, NPC 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 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 stated that earlier KPTCL and UPCL were having certain reservations and
KPTCL could be participate in the study at CEA. UPCL was also planning 2 x 800
MW expansion 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.
Critical Intra-regional transmission elements
400 kV Edamon-
Kochi
286 PGCIL
31st
TCC :
Sept
2018
Being monitored
under PRAGATI.
31st TCC: Line work
progressing
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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
660 MW
2019-20
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.
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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) Kancheepuram 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 lines in the Southern Region.
12.6.2 The following was noted in the TCC Meeting:
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 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-Tiruvalam 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.
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-Nelamangala rearrangement.
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400 kV Udumalpet- Palakkad D/C line
31st TCC: KSEBL stated that there was no constraint on this line. SRLDC stated that they
would examine it.
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 was 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 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 stated that they
would take up the additional requirement of 500 MVA ICT in the Standing Committee for
ratification.
400/220 kV 2 x 315 MVA ICTs at Vemagiri
31st TCC: SRLDC informed that even after commissioning of new ICT, the constraint
persisted.
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 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.
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TANTRANSCO informed that the downstream system had been commissioned.
Completion of Kamuthi bays (2 nos) at Karaikudi
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 informed the works may get completed by November 2017.
NLC ICTs
TANTRANSCO expressed concern over loading conditions of NLC ICTs and suggested
for additional ICT.
NLC 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/TANTRANSCO were 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.
12.8.2 The following was noted in the TCC Meeting:
TANGEDCO 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
needs to be periodically reviewed while planning / executing the project. At times, projects are
completed without much beneficial use and if the generators back out the financial burden gets
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 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
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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 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
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36 TN R.S. India Global Energy Wind 480
37 TN Suzlon Power Infrastructure Wind 1000
38 TN Suzlon Power Infrastructure Wind 350
39 TN Vestas Wind Technology India Wind 150
40 TN Wind Projects at Samugarengapuram Wind 600
41 TN Kamuthi Solar Park Solar 1000
42 KER Kottathara Project Wind 80
43 KER Vettathur Project Wind 80
44 KER Kuyilimala Wind Project Wind 14.25
45 KER Kasargode Solar Project Solar 200
Data not present in draft NEP
Vol.2(Trans.)
46 AP Gamesa Renewable Pvt. Ltd.(Kurnool) Wind 350
47 AP Gamesa Renewable Pvt. Ltd.(Dhone) Wind 300
48 KA Ostro Dakshin Power Pvt. Ltd. Wind 300
49 KA Orange Ashok Wind Power Wind 250
50 KA Renew Wind Energy (TN) Pvt. Ltd.
(Koppal)
Wind 400
51 TN Inox Wind Infrastructure Services Ltd Wind 500
52 TN Vagarai Suzlon wind farms Wind 200
53 TN Regen Wind Farm (Vagarai) Wind 600 or 384
54 TN Renew Power Ventures Pvt. Ltd.(Karur) Wind 400
56 TN Orange Sironj Wind Power Pvt. Ltd. Wind 200
57 TN Ostro Alpha Wind Pvt. Ltd. Wind 400
58 TN BLP Energy Pvt. Ltd. Wind 250
59 TN Greenmint Power Pvt. Ltd. Wind 200
60 TN Gamesa Renewable Pvt. Ltd.
(Thoothukudi)
Wind 400
61 TN Sitac Kabini Renewables Pvt. Ltd. Wind 250
62 TN Gamesa Renewable Pvt. Ltd. (Karur) Wind 200
63 TN Green Infra Wind Energy Ltd. (Tirpur) Wind 250
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.
TCC deliberations
13.3 It was noted that RE schemes are getting modified at times while some are getting dropped also.
TCC 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 was 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 were requested to ensure that infrastructure to implement
RE Framework either at ISTS/ISTS level was in place from the inception stage itself.
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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
interconnection
31st TCC:
Ready for
charging
8 No. of Line Bays
required
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
Dec 2018 Award placed in April
2016
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Third 400/220 kV
MVA transformer at
Tumkur
(Vasantnarsapur)
1 x 500 MVA
Dec 2018 Award placed in April
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.
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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 to discourage 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.
13.7.2 The following was noted in the TCC Meeting:
TANGEDCO 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 objective
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.
PCKL pointed out that transmission evacuation system planned for Wind/Solar had capacity
utilization factor of only about 19 %. Distributed Generation could lead to huge savings in
transmission and transmission losses as compared to concentrated generation at few
locations.
CTU informed that as per GoI notification (Sep 2016), Rs 8 lakhs/MW (or 30 % whichever is
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lower) provision for transmission has been provided as Central Financial Assistance (CFA).
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. Benefits would subsequently be passed on.
TSTRANSCO pointed out that they were also having Distributed Generation at 33 kV, 132
kV and 220 kV. More than 2,000 MW of RE has been synchronized. Developer was
connecting to the 33 kV/132 kV/220 kV S/S while balance system was being developed by
them.
On a query about grant for intra-state transmission projects linked with Solar evacuation,
CTU clarified that Rs 20 lakhs/MW grant is envisaged for a Ultra Mega Solar Power Project
under 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. 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 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.
13.8.2 The following was noted in the TCC Meeting:
TANGEDCO 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 stated that the issue could be addressed by NLDC since they are making the PoC
computations.
NLDC informed that regarding sharing of Webnet software, the DIC would need to approach
Hon‟ble CERC.
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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 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‟. The 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 was agreed that Chairperson, SRPC would be kindly requested to take up common issues
in this regard with Hon‟ble CERC.
All DICs were also suggested to take up specific issues / suggestions with the Task Force.
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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.
14.5 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 was 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
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„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 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.
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:
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 enquired about the generation availability since there were
some reported coal linkage issues at Kudgi. Full Generation was
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required in March / April 2018.
NTPC 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 taken 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 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.
BHAVINI
Kalpakkam
(PFBR)
I 500 Synchronization by
2017-18
COD by 2017-18
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31st TCC:
CTU 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 are 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 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
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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
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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.
17.4 The following was noted in the TCC Meeting:
NLDC 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 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 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.
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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.
TCC deliberations
18.3 Director (T&SO), KSEBL stated that they were agreeing to the proposal but some dues were to be
cleared by PED.
18.4 SE-I, PED said 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 claim 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.
18.5 Director (T&SO), KSEBL 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.
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 the 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.
MAPS/NPCIL again requested for the dues to be cleared at the earliest.
TANGEDCO informed that dues up to March 2017 had already been cleared and with regard to
the other dues, matter would be pursued.
TS/PCKL informed that the dues would be cleared by September 2017.
AP informed that earlier dues had been cleared and was pending for May & June 2017, which
too would be cleared.
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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.
MAPS/NPCIL 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.
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.
MAPS/NPCIL informed that mock drill could be taken up at 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.
MAPS/NPCIL informed that A/R for BHAVINI lines had been completed.
A/R for MAPS lines would be completed by December 2017. It was pointed out that in
compliance of the CERC Order, MAPS had earlier committed enabling of A/R by July 2017.
MAPS 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.
MAPS/NPCIL 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.
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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.
MAPS/NPCIL 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.
MAPS/NPCIL 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 stated that both the KKNPP units should be back by Oct 2017
since the loads pickup.
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 injection from Unit 3 & Unit 4 was 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.
MAPS/NPCIL informed that there were certain technical difficulties and other generators
of similar make such as RAPS were also following similar injection pattern.
SRLDC 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.
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SRLDC 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.
20.3 TCC noted the above.
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:
21.2 The following had been noted in earlier Meetings:
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
21.3 The following was noted in the TCC Meeting:
MS, SRPC 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 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 informed that they had availed two overhauls and performance would increase.
Presently, the availability was 100 %.
NTECL informed that Unit-3 was expected back by 15th
November 2017.
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
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22. REVIEW OF ULDC / SCADA/COMMUNICATION
22.1 Status of pending items is as follows:
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
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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 PGCIL SR II E-mail dated 16.06.2017(Annexure-XXXVIII) had informed that award was 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.
22.4 The following was noted in the TCC Meeting:
MS, SRPC 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
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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.
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
126
Pending in
Hyderabad,
Khammam
and
Vemagiri.
20 Supplied: 107
Commissioned:
97
Integrated: 85
SR
II
41 142 Completed 39 Supplied: 138
Commissioned:
112
Integrated: 110
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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 2107
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.
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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.
23.3 The following was noted in the TCC Meeting:
APTRANSCO 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 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.
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 was noted in the earlier Meetings:
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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.
24.3 TCC noted the above.
25. TTC/ATC
25.1 In earlier Meetings the following had been noted:
In the 4th
Meeting of NPC held on 10th
December 2015 (MoM dated 1.1.2016), it had been
decided that to begin with, power system study for assessment of operational limits / power
transfer capability for each state would be done by the concerned RLDC in association with
concerned SLDC. Monthly TTC/ATC would be uploaded by SLDCs in their respective
websites and also communicated to concerned RLDC & NLDC subsequently.
Converged PSSE base cases to be furnished to SRLDC.
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 was noted :
APTRANSCO 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 also informed that Nodal Officer and Study Group nominations 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.
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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.
25.3.3 TCC noted the above.
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.
25.4.4 The following was noted in the TCC Meeting:
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 shutdown 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 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)
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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 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 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 was 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.
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.
26.3 TCC noted the above.
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:
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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.
27.2 In earlier Meetings the following had been noted:
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.
27.3 The following was noted in the TCC Meeting:
APTRANSCO stated that PSDF funding for 3rd
ERS would enable them to take up
procurement in a timely manner.
TSTRANSCO informed that they had floated the tender and it would be finalized shortly.
KSEBL informed that the DPR was being prepared and they too would approach for PSDF
funding.
TANTRANSCO informed that it was being re-tendered and they would require PSDF
funding.
NPC 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 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 stated that the functional requirement had been communicated by MoP and the
status was being reviewed at the highest levels. He suggested to NLDC/NPC that requests of
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SR states be considered since ERS was critical and also relatively not too costly.
NPC 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 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.
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
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Talguppa 125 39th
SC
they had taken up with
CEA for reviewing.
During studies no reactors
had been considered in
that area and arrived at
125 MVAR requirement.
Now two reactors had
come at Guttur and
Talaguppa.
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
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KPTCL and KPTCL will
discuss with PCKL to sort
out issues. UPCL had
submitted all the
information as required.
28.2 The following was noted in the TCC Meeting:
TSTRANSCO 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 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 was noted in the TCC Meeting:
PGCIL informed that the project was awarded in March 2017 with a schedule of June
2019.
PGCIL clarified that PSDF funding was envisaged at 80 %.
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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
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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.
28.6.3 The following was noted in the TCC Meeting:
TSTRANSCO requested NLDC/NPC to consider the two Capacitor proposals for PSDF
funding. It was noted that the report of CPRI was awaited.
MS, SRPC 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 Rs13,38,631/- 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.
TCC noted the above.
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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.
TCC noted the above.
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
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
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TCC 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.
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,
timeline for complying with
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the remaining pending
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,
timeline for complying with
the remaining pending
recommendations (13 in no.)
is October, 2017.
7 KPTCL 31.05.2017 31.05.2017 42.25 Based on the status furnished,
timeline for complying with
the remaining pending
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,
timeline for complying with
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.
31.4 The following was noted in the TCC Meeting:
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.
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
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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
32.3 PGCIL 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.
32.4 PGCIL was suggested to furnish details of spare ICTs/Reactors along with the Standing
Committee/SRPC approvals.
32.5 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.
32.6 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.
33.1.2 In earlier Meetings, the following had been noted:
AMDS logic was finalized as OD >250 MW or 20 % of Schedule, whichever lower, for 15
minutes when frequency < 49.8 Hz.
SRLDC & SRPC had suggested that new set points at 49.9 Hz be adopted.
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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 recommended for retaining the set points which would be reviewed in the next TCC
meeting.
33.1.5 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
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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
33.2.2 In earlier Meetings, the following had been noted:
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.
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35.2.4 The following was noted in the TCC Meeting:
APTRANSCO 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 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:
Number 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).
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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.
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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.
33.3.9 The following was noted in the TCC Meeting:
SRLDC 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 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.
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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.
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33.5.2 An IMD workshop had been organized by SRLDC on 12th
July 2017 with good participation
from most of the entities.
33.5.3 TCC noted the above.
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.
33.6.3 The following was noted in the TCC Meeting:
SRLDC 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 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 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.
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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 TCC 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
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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 TCC urged generators to take 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,
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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.
33.10.5 The following was noted in the TCC Meeting:
NLC 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 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.
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 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 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 started 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.
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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 analyse 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.
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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
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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
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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
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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.
TCC 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
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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
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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.
34.7 The following was noted in the TCC Meeting:
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.
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.
35.3 The following was noted in the TCC Meeting:
KPTCL 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.
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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 TCC 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,
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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]
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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 effected 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 TCC 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.
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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.
38.2 The following was noted in the TCC Meeting:
PGCIL agreed to coordinate with the concerned entities and complete the works by December
2017.
APTRANSCO 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
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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.
39.3 TCC noted the above.
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.
40.4 The following had been noted in earlier Meetings:
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.
40.5 TCC noted the above.
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 TCC suggested that respective entities may take necessary action to close the pending issues.
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42. COMMERCIAL COMMITTEE ISSUES
42.1 Following issues were brought to the attention of SRPC/TCC:
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
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(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.
42.2 TCC noted the above.
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.
43.3 The following was noted in the TCC Meeting:
NPC 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 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
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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.
44.4 TCC noted the above.
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
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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.
45.4 The following was noted in the TCC Meeting:
TANGEDCO 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 has 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).
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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
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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
commissioned on 31.03.2017 by APTRANSCO.
220 kV D/C line from 220 kV PS-3 to PS- 4 in Kurnool district of 7.412 ckm was
commissioned on 28.03.2017 by APTRANSCO.
PTR-1 at 220/33 kV Gani PS-4 in Kurnool district of 80 MVA Capacity was commissioned on
05.03.2017 by APTRANSCO.
Transformer at 220/132 kV SS Kuppam in Chittoor district of 100 MVA Capacity was
commissioned on 30.03.2017 by APTRANSCO.
PTR 4 at 220/33 kV SS at Gani PS-1 in Kurnool district of 80 MVA Capacity was
commissioned on 31.03.2017 by APTRANSCO.
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
commissioned on 31.03.2017 by TSTRANSCO.
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
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“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
Vijayawada Substation.
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
Vijayawada Substation.
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
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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
17.04.2017 by APTRANSCO.
220/132/33 kV SS Gollapuram in Anantapur district of 150 MVA Capacity was
commissioned on 22.04.2017 by APTRANSCO.
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
commissioned on 03.05.2017 by TSTRANSCO.
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.
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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.
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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
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May 2017
Highest 32.55 50.69 45.93 40.82 29.08 49.73 27.33
Date (Day) 01.05.2017
(Monday)
09.05.2017
(Tuesday)
08.05.2017
(Monday)
11.05.2017
(Thursday)
23.05.2017
(Tuesday)
19.05.2017
(Friday)
08.05.2017
(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.
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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 TCC 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.
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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‟.
49.3 The following was noted in the TCC Meeting:
MS, SRPC 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 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 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 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 stated that this was a techno-commercial issue. KPTCL stated that they had approved
LTA considering that Railways would remain consumer of Discoms.
NPC stated that deemed licensee status had been granted to Railways under Section 14 by
GoI and thus Railways is distribution licensee.
CTU 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 reiterated that states needed to take necessary actions to implement the MoP
allocation and this was also being monitored under PRAGATI.
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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.
50.3 TCC noted the above.
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.
51.3 TCC noted the above.
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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.
52.2 TCC noted the above.
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.
53.2 TCC noted the above.
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.
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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.
54.5 TCC noted the above.
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.
55.3 TCC noted the above.
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.
56.2 The following was noted in the TCC Meeting:
KSEBL 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 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 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.
57.2 The following was noted in the TCC Meeting:
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APGENCO 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 stated that the issue could be deliberated bilaterally.
It was noted that the issue could be deliberated further in the SRPC Meeting.
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 recommended that URS could also be reallocated to the non-beneficiaries in Southern Region.
Chairperson, SRPC may be kindly requested to take up this matter with MoP.
59. CONCLUSION
59.1 Chairperson, TCC thanked all the utilities for their cooperation and also fruitful deliberations. He
also thanked the host KSEBL for the excellent arrangements made for conduct of the Meeting.
60. DATE & VENUE OF THE NEXT TCC MEETING
It was agreed to have the next Meeting of TCC, one day prior to 33rd
Meeting of SRPC.
*******