A. SRPC Members - Southern Regional Power Committee

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Distribution List:

A. SRPC Members: 1) Shri Rajesh Lakhoni, Chairperson, SRPC & CMD, TANGEDCO, Chennai 2) Shri B K Arya, Member (GO & D), CEA, New Delhi. 3) Dr. Srikanth Nagulapalli, CMD, APTRANSCO, Vijayawada 4) Shri B Sreedhar, Managing Director, APGENCO, Vijayawada 5) Shri K Praveen Kumar, Director (Grid &Tr.Mgmt), APTRANSCO, Vijayawada 6) Shri J Padma Janardhana Reddy, CMD, APCPDCL, Vijayawada 7) Dr N Manjula, Managing Director, KPTCL, Bengaluru 8) Shri V Ponnuraj, Managing Director, KPCL, Bengaluru 9) Shri V Krishnappa, Managing Director, PCKL, Bengaluru 10) Shri G R Chandrashekaraiah, Director (Transmission), KPTCL, Bengaluru 11) Shri B Gurumurthy, Chief Engineer (E), SLDC, KPTCL, Bengaluru

12) Dr B Ashok,CMD, KSEBL, Thiruvananthapuram

13) Shri Rajan Joseph (Transmission & System Opn), KSEBL, Thiruvananthapuram

14) Shri Rajkumar S, Director (Distribution & IT), KSEBL, Thiruvananthapuram

15) Shri Siji Jose, Director (Generation -Electrical), KSEBL), KSEBL, Thiruvananthapuram 16) Shri S Shanmugam, Managing Director, TANTRANSCO, Chennai

17) Shri M. Senthilvel,, Director (Operation), TANTRANSCO, Chennai

18) Shri S Shunmugam, Director (Transmission Projects), TANTRANSCO, Chennai

19) Shri M. Sivalingarajan, Director (Distribution), TANGEDCO, Chennai 20) Shri D Prabhakar Rao, CMD, TSTRANSCO, Hyderabad 21) Shri D Prabhakar Rao, CMD, TSGENCO, Hyderabad 22) Shri B Narsinga Rao, Director (Grid Operations), TSTRANSCO, Hyderabad 23) Shri A Gopal Rao, CMD, TSNPDCL, Warangal 24) Shri Devesh Singh, Secretary (Power), Govt. of Puducherry, Puducherry 25) COO, CTUIL, Gurugram 26) Shri A K Gupta, Director (Commercial), NTPC, New Delhi 27) Shri Shaji John, Director (Power), NLCIL, Neyveli 28) Director (Finance), NPCIL, Mumbai 29) Shri Kedar Ranjan Pandu, CEO, NTECL, Vallur 30) Shri Jayadeb Nanda, Chief Operating Officer (O&M), UPCL, Bengaluru 31) Shri Jyotiprakash Panda, Head-Regulatory & Power Sales, JSWEL, New Delhi 32) Shri K S Gopalakrishnan, CEO, NTPL, Tuticorin 33) Shri Vipul Tuli, Managing Director, SEIL, Gurugram 34) Shri Mohit Sighal, Vice President, Coastal Energen Pvt Ltd., Chennai

35) Shri Bhavani Prasad, Business Head, IL& FS Tamil Nadu Power Company Limited, Chennai 36) Shri Venugopal Keshanakurthy, CEO, HNPCL, Hyderabad 37) Shri Ajit Kumar, Director (Commercial), PTC India Ltd., New Delhi 38) Shri Amit Garg, Chief Executive Officer, TPTCL, Noida 39) Shri S S Barpanda, Director (Market Operations), POSOCO, New Delhi 40) Shri V Suresh, Executive Director, SRLDC, POSOCO, Bengaluru

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B. TCC Members:

1) Shri S Shanmugam, Chairperson (TCC) & Managing Director, TANTRANSCO, Chennai

2) Shri K Praveen Kumar, Director (Grid & Tr. Mngmnt.), APTRANSCO, Vijayawada

3) Shri G Chandrasekhara Raju, Director (Thermal), APGENCO, Vijayawada

4) Director (operations), APCPDCL, Vijayawada

5) Shri G R Chandrashekaraiah, Director (Transmission), KPTCL, Bengaluru

6) Shri B Gurumurthy, Chief Engineer (E), SLDC, KPTCL, Bengaluru

7) Shri K S Prasanna, Additional Director (Projects), PCKL, Bengaluru

8) Shri Narendra Kumar, Technical Director, KPCL, Bengaluru

9) Shri Rajan Joseph (Transmission & System Opn), KSEBL, Thiruvananthapuram

10) Shri Rajkumar S, Director (Distribution & IT), KSEBL, Thiruvananthapuram

11) Shri Siji Jose, Director (Generation -Electrical), KSEBL), KSEBL, Thiruvananthapuram

12) Shri M. Senthilvel,, Director (Operation), TANTRANSCO, Chennai

13) Shri S Shunmugam, Director (Transmission Projects), TANTRANSCO, Chennai

14) Shri M. Sivalingarajan, Director (Distribution), TANGEDCO, Chennai

15) Shri B Narsinga Rao, Director (Grid Operations), TSTRANSCO, Hyderabad

16) Shri T Jagath Reddy, Director (Transmission), TSTRANSCO, Hyderabad

17) Shri B Lakshmaiah, Director (Thermal),TSGENCO, Hyderabad

18) Shri P Mohan Reddy, Director (Projects), TSNPDCL, Warangal

19) Shri Ashok Pal, Dy.COO, CTUIL, Gurugram

20) Shri T Chanemougam, Superintending Engineer-cum-HOD, Elec. Dept., Puducherry

21) Shri Sanjay Madan, Regional Executive Director, SRHQ, NTPC, Secunderabad

22) Shri A Ravindran, Executive Director (Thermal), NLCIL, Neyveli.

23) Shri Sandeep Sarwate, Addl. Chief Engineer(Transmission & Electrical), NPCIL, Mumbai

24) Shri P Siva ramakrishnan, General Manager(O&M), Vallur TPS,NTECL, Vallur

25) Shri K Suryaprakash, VP and Head of Plant, JSWEL

26) Shri Uday Trivedi, Vice President (P & M), UPCL, Bengaluru

27) Shri R S Kumaraswamy, Advisor (Electrical). CEPL,Tuticorin

28) Shri Ramachandra Bhat, Station Head, IL&FS Tamil Nadu Power Company Limited

29) Shri K S Gopalakrishnan, Chief Executive Officer, NTPL, Tuticorin

30) Shri Raghav Trivedi, Business Head -Thermal, SEIL, Gurugram

31) Shri S Mukharjee, Sr VP (O & M), & Plant Head, HNPCL, Hyderabad

32) Shri Harish Saran, Executive Director(Marketing), PTC India Ltd., New Delhi

33) Shri Bikram Singh, Chief-Marketing, TPTCL, Noida

34) Shri Hemant Jain, Chief Engineer (GM), CEA, New Delhi

35) Ms Rishika Sharan, Chief Engineer (NPC), CEA, New Delhi

36) Shri V Suresh, Executive Director, SRLDC, POSOCO, Bengaluru

C. Special Invitees:

1) Director (Operations), PGCIL, Gurugram 2) Executive Director (SR- I), PGCIL, Secunderabad

3) Executive Director (SR- II), PGCIL, Bengalure

भारत सरकार

Government of India

विद्युत मंत्रालय

Ministry of Power

कें द्रीयविद्युत प्राविकरण

Central Electricity Authority

दविण िेत्रीय विद्युत सवमवत SSSooouuuttthhheeerrrnnn RRReeegggiiiooonnnaaalll PPPooowwweeerrr CCCooommmmmmiiitttttteeeeee

तकनीकी समन्िय उप सवमवत एिं दविण िेत्रीय विद्युत सवमवत

की उनतालीस िीं बैठकों की काययसूची

Agenda for 39

th Meeting of TCC / SRPC

Scheduled on 03.12.2021 (TCC) & 06.12.2021 (SRPC)

(((TTThhhrrrooouuuggghhh VVViiidddeeeooo CCCooonnnfffeeerrreeennnccciiinnnggg)))

Agenda for the 39thmeetings of TCC (03.12.2021) & SRPC (06.12.2021) Page 1 of 70

Southern Regional Power Committee Bengaluru

Agenda for 39th meeting of TCC/SRPC (To be held on 3rd / 6th December 2021 through VC)

I. Introduction The 39th Meetings of the Technical Coordination Sub-Committee (TCC) is scheduled on 03rd December 2021and Southern Regional Power Committee (SRPC) on 06th December 2021through Video Conferencing (VC).

II. Confirmation of the Minutes a) 38th Meeting of TCC / SRPC: The combined Minutes of 38th TCC (22.12.2020) &SRPC

(23.12.2020) meetings were circulated vide letter dated 22ndJanuary 2021.

Minutes of the Meetings may be confirmed.

III. Action Taken Report (ATR) on the decisions in the 38th Meeting of SRPC

S No. Item No. in MoM / Decision Action Taken Remarks

1 C.3 Deviation Settlement Mechanism - Payable increased on Post-facto due to variation in Nuclear generation

Chairperson, SRPC vide letters dated 01.02.2021 has taken up with DAE, MoP and CERC.

Copy of the letters at Annexure-ATR.1

Decision: Chairperson, SRPC to take up with DAE/MoP/CERC to bring NPCIL stations in the ambit of ABT.

2 C.4 Fifth Amendment in CERC (Deviation

Settlement Mechanism and related matters) Regulations

Chairperson, SRPC vide letter dated 29.12.2020 has taken up with CERC.

Copy of the letter at Annexure-ATR.2

Decision: Chairperson, SRPC to take up with CERC for restoration of 12 time block sign change/Regulation 7(10)(a) of DSM fifth amendment and also for deletion of 6 time block sign change /Regulation 7(10)(b) permanently.

3 C.6.Transmission charges / sharing related issues Chairperson,

SRPC vide letters dated 07.01.2021 has taken up with CERC and MoP.

Copy of the letters at Annexure-ATR.3 Decision: Chairperson, SRPC to take up with

MoP/CERC for declaring the Raigarh (Chhatisgarh)-Pugalur (TN) HVDC & Pugalur (TN) – Trissur (KER) HVDC system as national/strategic project/national component for sharing the transmission charges


4 C.8.NNTPP Unit-II: Drawal of start up power and

injection of infirm power Chairperson, SRPC vide letter dated 23.12.2020 has taken up with CERC.


Decision: Chairperson, SRPC to take up with CERC for granting special permission to unit-2 of NNTPP for injection of infirm power under DSM up to 31.01.2021.

5 C.9.Recovery of transmission charges due from

BHAVINI as per CERC order dated 29.04.2015 in Petition No.105/TT/2012

Chairperson, SRPC vide letter dated 07.01.2021 has taken up with DAE& BHAVINI


Decision: Chairperson, SRPC to take up with DAE/BHAVINI for settlement of the outstanding transmission charges dues.

6 C.10.Southern Regional Power Committee

(Transmission Planning) Chairperson, SRPC vide letter dated 07.01.2021 has taken up with CERC.


Decision: Chairperson, SRPC to take up with MoP for revision of ToR of RPC (TP)/ NCT and inclusion of DISCOMs as member in SRPC (TP).

7 C.11.MoP Amendment in "Equity lock-in period"

in the SBDs for selection of Transmission Service Provider (TSP) through TBCB

Chairperson, SRPC vide letter dated 07.01.2021 has taken up with MoP.


Decision: Chairperson, SRPC to take up with MoP to withdraw the amendment in equity lock in period.

8 C.12.Delay in hosting national net SCED benefits distribution statement by NLDC

MS,SRPC vide letter dated 29.12.2020


Decision: MS, SRPC to take up with CMD, POSOCO for timely publishing of SCED benefit sharing statements.

9 C.13.Deficit in DSM pool of a region to be met

from the surplus of other regions Chairperson, SRPC vide letter dated 29.12.2020 has conveyed the decision to CERC.


Decision: Chairperson, SRPC to convey CERC that ERPC proposal regarding the surplus DSM pool transfer of a region to another deficit region before transferring it to PSDF not to be considered for implementation.

10 O.1.Establishment of Unified Network

Management System (UNMS) for ISTS communication

SRPC Secretariat had put up the consolidated views to Chairperson, SRPC. There was no clear concurrence from APTRANSCO, KSEBL and TANTRANSCO.

Decision: SRPC Secretariat to consolidate the views of constituent states and the outcome


would be communicated to PGCIL/CTU Chairperson, SRPC has advised that the issue may further be deliberated in the next meetings of TCC/SRPC.

IV. Agenda items for Deliberation (i) Operation

O.1. Establishment of Unified Network Management System (UNMS) for ISTS communication

1.1. The Unified Network Management System (UNMS) was discussed in the various Meetings of OCC, Special Meetings (07.11.2019& 07.12.2020), TCC meetings (36th, 37th& 38th) and in SRPC meetings (37th& 38th).

1.2. The following had been noted in earlier meetings:

a) Following functions (Service Assurance, Service Fulfilment, Web Consoles and Ticketing etc.) are considered in the proposed U-NMS (Applications / Functions may vary at NLDC/RLDCs/SLDCs – depending upon the Operational / Administrative Requirements):

i) Control Centre in NLDC ii) Control Centre in RLDCs iii) Workstation based Control Centre in SLDCs

a) CERC Communication Regulations requires all users of CTU, NLDC, RLDCs, SLDCs, STUs shall maintain the communication channel availability at 99.9% annually Provided that with back up communication system, the availability of communication system should be 100%.

b) Central Electricity Authority (Technical Standards for Communication System in Power System Operations) Regulations notified in Feb 2020 stipulates that user shall keep evidence of compliance on availability for the previous two calendar years plus the current year for all the interfaces which are in operation.

c) CEA, Communications regulation specifies network management system shall have features to store necessary information and facility to generate report on communication system availability of major equipment as well as the data channels on daily or weekly or monthly or annually basis. It also envisages centralised monitoring shall be in main and back-up control centre architecture with centralised database and twenty-four hours maintenance on all days.

d) It was informed that there is no provision in the existing communication infrastructure for (i) data retention for a period 3 years (including current year), (ii) automatic report generation which is required for certification & monitoring and (iii) centralised supervision.

e) PGCIL had informed that the cost for implementation is Rs. 109 Crores in SR and Rs. 5 Crores for AMC/year. The useful life would be seven years as in the case of EMS SCADA packages of SLDCs and POSOCO. Also, the cost of National Level UNMS (Rs.109 Crores)


needed to be shared by all the regional constituents. NR and NER had adopted for Tariff based funding.

1.3. In the 38th meeting of SRPC (23.12.2020):

i) PGCIL:

UNMS scheme would be implemented with 70 % through PSDF grant and 30 % equity by PGCIL as the owner of the project along with contract forAMC.

If 100 % funding through PSDF, the scheme would be implemented as a consultancy project (an undertaking project as a deposit work) with undertaking charges.

ii) Decision:

a) All the constituents states to furnish clear/specific views in writing on the following:

(i) Approval of UNMS scheme (technically).

(ii) Funding Mechanism (70 % grant from PSDF and 30 % equity by PGCIL or 100 % funding through PSDF)

b) SRPC Secretariat to consolidate the views of constituent states and the outcome would be communicated to PGCIL/CTU.

1.4. Subsequently, the constituent sates had furnished their views (Annexure-O.1.4). Summary of

the views are as follows:

S. No.

Constituent/Utility Observation/Approval Funding

1 Andhra Pradesh/ APTRANSCO

The existing NMS in service are fulfilling the functions such as monitoring, integration of network elements in APTRANSCO communication system.

-

2 Karnataka/ KPTCL

Agreed in principle (technically) 100% PSDF

3 Kerala/KSEBL The proposal can be considered with more clarity in the technical administrative matters in the Scheme.

-

4 Tamil Nadu/ TANTRANSCO

Already equipped with NMS/EMS of multiple vendors for monitoring the State Communication System. If it is to be integrated in UNMS project100% grant through PSDF (otherwise TANTRANSCO may kindly be excluded from UNMS Project)

100% PSDF

5 Telangana/ TSTRANSCO

Management has approved participation of TSTRANSCO.

100% PSDF

6 Puducherry/EDP The specification is generally acceptable, specific requirement of UT of Puducherry to be obtained before tenders are floated.

100%

PSDF

Note: It may please be noted that there is no clear concurrence from APTRANSCO and

KSEBL.

1.5. PGCIL vide letter dated 31.12.2020 (Annexure-O.1.5) has conveyed that “POWERGRID

agree to approach PSDF on funding for 70% grant from PSDF and 30 % own equity after


SRPC approval. In case PSDF funding is not approved, UNS scheme be approved for implementation under tariff route”.

1.6. The views of the constituents had been put up to Chairperson SRPC. Chairperson, SRPC has advised that the issue may further be deliberated in the next meetings of TCC/SRPC.

1.7. In the first meeting of the ‘Standing Committee on Communication System Planning in Power Sector’ held on 9th March, 2021, CEA had apprised that UNMS being a regulatory requirement, its implementation needs to be expedited and utilities are requested to ensure its smooth integration. If any issue arises regarding integration with centralized NMS, the matter should be referred to CEA.

1.8. PGCIL vide letter dated 26.07.2021 (Annexure-O.1.8) has informed that the U-NMS scheme

has already been approved in NRPC, NERPC and in ERPC as per regulated tariff mechanism. For NR and NER Region Bids have already opened and it is under award stage and for ER Region it is under Tendering Stage. Further for WRPC it is in advance stage of discussion.

POWERGRID’s submission: It is requested that SRPC may approve the scheme at earliest so that the work may be taken up in parallel to other regions.

1.9. Agenda for Deliberation /Decision:

a) Concurrence of APTRANSCO and KSEBL.

b) Funding from PSDF

c) Next course of action by PGCIL

This may please be deliberated.

O.2. URTDSM (PMU) Project in Southern Region

2.1. The following had been noted in the earlier meetings:

a) In the 36th Meeting of SRPC (12.07.2019), it was noted that the SLDCs to make use of the Analytical Applications in close co-ordination with SRLDC. Issues, if any, needed to be brought to the attention of PGCIL (Smart Grid) & IIT B.

b) SR states had requested for Online Training on PMU based state estimator, assessment of angular, voltage and frequency stability and control through PSS, FACTS devices and HVDC controls, Development of improved restoration schemes, Network parameter validation, dynamic model validation etc. PGCIL to facilitate the training.

c) All the states had furnished the requirement for Phase II. SRLDC had stated that once the OF availability is received from PGCIL, they would discuss with SR-I & SR-II (if required with states also) and finalize the PMU requirements for Phase-II for SR. RE pooling stations, LI SS, STATCOM locations, Phase Shifting Transformers etc would be considered while finalizing the PMU requirement. Communication availability would also to be looked into.

d) SRLDC had furnished the list of new Analytics which could be covered in Phase II scope.

1. Real Time Automated Event Analysis Tool 2. Oscillation Source Location 3. Real time Inertia Estimation Tool


4. Big data analytics tool / engine

e) CTU/PGCIL had informed that training had been provided in two stages for all the constituents. Further requirement if any may be put up to CTU and action will be taken accordingly. 6th Analytic Protocol was delayed due to COVID-19 Issues in Maharashtra and it would be taken up in December 2020. Requirements have been received from all the states for Phase II. Additional location for installation for PMUs furnished by SRLDC is not in line with already approved criteria for PMU implementation.

f) On the requirement of PMUs for Phase II,CTU/PGCIL had informed that PMU requirement was worked out for Phase-I based on the philosophy as approved in the Joint Study Committee Meeting taken by CEA in March 2012. Based on the same philosophy CTU had assessed PMU requirement of Phase-II also. Subsequently POSOCO came up with a modified philosophy in which more PMUs were suggested to cover each generating station, FACT devices, STATCOM, Converter Transformers, SVCs, FST, Lift Irrigation schemes, Renewable Pooling Stations and also some more analytic applications. This change in philosophy was deliberated in a meeting taken by Chairperson, CEA wherein Chairperson, CEA had advised that the change in philosophy brought out by POSOCO may be discussed in next NPC Meeting and CTU had agreed to put up this issue as an agenda item for next NPC Meeting.

g) After finalization of the philosophy on Pan India basis, CTU would work out the requirement in consultation with the POSOCO/states. The finalised requirement of PMUs would be put up to SRPC for approval.

2.2. Subsequently, PGCIL and SRLDC had arranged training program on URTDSM Phase I on 01st& 02nd February 2021 (by SRLDC) and on 03rd& 04th February 2021 by PGCIL/IIT Bombay.

2.3. KSEBL, TANTRANSCO & TSTRANASCO had furnished the feedback to CTU w.r.t. URTDSM Phase-I project (Annexure-O.2.3).

2.4. In the 10th meeting of National Power Committee (NPC) held on 09th April 2021 deliberations, NPC decided that a Sub-Committee would be formed under the Chairmanship of Member Secretary, WRPC with representatives from POSOCO, CTU, POWERGRID, all RPCs/NPC. The Sub-Committee shall discuss on the uniform philosophy of PMU locations, new analytics and requirement of up gradation of Control Centre under URTDSM project and submit its recommendations to the NPC.

2.5. Subsequently, CEA, NPC Division vide letter dated 20.09.2021(Annexure-O.2.5) had

communicated regarding the constitution of Sub-Committee on the uniform philosophy of PMU locations, new analytics and requirement of up gradation of Control Centre under URTDSM project. Shri P Suresh Babu, SE, TS SLDC, TSTRANSCO, Shri J B Len, EE (Protection), SRPC, and Shri T Sivakumar, EE(PC&I), TANTRANSCO are the Members representing SRPC in the Sub Committee.


CTU to work out the requirement in consultation with the POSOCO/states after finalization of the philosophy on Pan India basis.


O.3. Up gradation / Replacement of SCADA/EMS Systems in SR

3.1. The following had been noted in the meetings of TCC/SRPC:

a) SRLDC had intimated that the existing SCADA/EMS system in SRLDC and SLDCs of SR were commissioned in 2015-16 and will be completing a tenure of five years. POSOCO had proposed to go ahead with upgradation/replacement of existing SCADA system at RLDCs with a commissioning time frame of early 2023.All SLDCs are invited to partner with POSOCO and together implement a unified upgradation/replacement of the existing SCADA/EMS system.

b) Further, SRLDC had informed that Technical Specification (TS) for the scheme had already been circulated and comments were yet to receive from the states. All the states were requested to revert back with their specific wish list like adoption of latest technology, additional features to be included, life time of 15 years etc. If 15 years life time is desired, there is a need for inbuilt AMC cost as well as interim cost (software/hardware upgradation cost) with OEM which is to be considered in the tendering process itself. Sizing of the system (after 15 years) and assessing requirements for such scenario is tedious. If all states are agreeable for single vendor, it may be negotiated for 15 years life time. States were requested to furnish the observations/comments by end of January 2021 on the specifications already circulated.

c) APTRANSCO had stated that they would go ahead with up-gradation on their own. APTRANSCO opined that it must be developed across India on a common architecture/platform. CMD, APTRANSCO had taken up the matter with MoP to develop a common in-house architecture (including proper specifications) taking views from CTU/PGCIL, MNRE, POSOCO, IITs/NITs, CDAC etc., which can be used by all states. APTRANSCO had informed that they would go ahead with up-gradation of SCADA on their own by adopting the Technical Specifications finalised by POSOCO.

d) CTU had informed that MoP vide its Order dated 20.10.2020 has constituted a committee under the Chairmanship of Member (Power System), CEA to explore the possibilities of development of indigenous SCADA system for Indian Power Sector based on the communication received from CMD, APTRANSCO. CEA had requested POSOCO/ states to furnish the issues/challenges (technical/contractual) being faced in existing SCADA. POSOCO may wait for the Committee Report.

e) KPTCL had informed that in view of completion of life of existing SCADA, going ahead with implementation of SCADA on their own. The request for PSDF funding was rejected by the competent authority citing that State-wise funding is not available. They would adopt the finalized Technical Specification by POSOCO. Regarding the provision for 15 years life time, SCADA may not support for such long period and that may be the reason for assuring a life time of 7 years only for ULDC scheme. They would adopt the TS being finalized by POSOCO. ICCP standards have already evolved and the same would be adopted. All these aspects had been appraised to higher management and approval is awaited.


f) KSEBL had informed that feedback for specification would be furnished after receiving inputs from their SCADA team. It is prudent to wait for Committee Report to finalize the TS.

g) TANTRANSCO had informed that the matter had been taken up with higher management for approval to join with POSOCO’s proposal. Draft memorandum and agreement would be submitted to the management for approval. TANTRANSCO requested that PSDF fund may be got granted for SCADA up gradation. The comments and additional requirements would be communicated with the concurrence from management. Specific ICCPs between REMC & URTDSM which were already commissioned may also be considered.

h) TSTRANSCO had informed that they were going ahead with the RLDC proposal and in the process of getting management approval. Main SLDC as well as back SLDC was planned to bring under this new proposal. Specifications should be according to latest technology and should assure a long-term life time of at least 15 years.

i) POSOCO had informed that based on the methodology suggested by POSOCO, a Committee would be formed with the participation from SLDCs(willing to move along with POSOCO proposal) and RLDCs for finalization of the requirements of states. Cost could be estimated after knowing the requirements from the states. After discussion with all participating states, RLDCs etc., a system as required by all stakeholders would be implemented. Developing indigenous SCADA system is a long term goal and may be available for next upgradation and it may not be practical for the up gradation under discussion since many applications are involved and needs more testing etc.

j) TCC had suggested that POSOCO to include the recommendations of SCADA Committee constituted by MoP suitably in SCADA up-gradation projects of various states as and when the report is finalized.

3.2. The following had been noted in the 182nd (09.09.2021 ) & 183rd (08.10.2021)Meetings of OCC:

i. PCD Division, CEA is preparing a database for requirement of SCADA software at control centers and substation level.PCD Division has requested to provide details of requirement for up gradation/new installation of SCADA/EMS system at State level Load Dispatch Centers (including Area LDC, Sub-LDC, Back-up LDC) coming under respective regions.

ii. TSTRANSCO had informed that the existing main SLDC/SCDA/EMS system is supplied by M/s Alstom and was taken over by GE T & D limited and the AMC is going to end by 12.02.2023 as per the agreement. Up gradation is planned with SRLDC, TN and Kerala. In this regard MoU with SRLDC is planned to be signed shortly. Requested that the entire project cost including AMC cost may be funded from PSDF. It is understood from CEA/NLDC that at National Level the proposal had been firmed up to get the SCDA upgradation/EMS works to be funded from PSDF. In view of this, from SR also representation may be given to CEA/NLDC to consider the scheme for PSDF funding. The regional level representation would have more impact than individual state representation. TSTRANSCO is planning to submit the complete DPR for Sub Station upgradation to NLDC along with the SCADA up gradation details. TN SLDC had endorsed the views of TSTRANSCO.


iii. SRLDC had informed the following:

(i) Discussions were held with Telangana, Kerala and Tamil Nadu SLDCs on up gradation process & timelines. MOU for joint SCADA up gradation has been signed by SRLDC &Telangana SLDC. MOU for joint SCADA up gradation signed by SRLDC and sent to Kerala SLDC for signing at their end. As per meeting with TN SLDC, decision on non-linking of SCADA/EMS up gradation with PSDF funding is yet to be taken at TN SLDC. Approval is under process for joint SCADA/EMS upgradation at Puducherry.

(ii) MOU signing for joint SCADA/EMS upgradation needed to be delinked from availability of PSDF funding. SLDCs are required to submit DPR to Nodal agency for PSDF funding. POSOCO would provide necessary help in preparation of DPR. He informed that the TS framed by POSOCO had been forwarded to all the constituents and some observations have been received which are taken care off. One to one discussions are going on with Telanagana, Kerala & Tamil Nadu SLDCs on various aspects like time-line of upgradation as well as how to go ahead.

iv. APSLDC had informed that they had communicated to NLDC regarding the requirement

and DPR would be submitted. APTRANSCO desired to know whether PSDF funding

would be ensured for SCADA up gradation and stated that in case PSDF is not sanctioned APTRANSCO would implement the scheme by themselves.

v. TSTRANSCO had communicated to SRLDC and DPR would be submitted to NLDC shortly.

vi. TANTRANSCO had informed that they are moving along with SRLDC without linking with PSDF funding, Management approval had already received for the same. ED SRLDC suggested TANTRANSCO to furnish the DPR to NLDC, so that if it is approved TN may be benefitted, POSOCO also had taken up with NLDC in this regard.

vii. KSEBL had informed that moving along with SRLDC. Board approval had been received for signing of MoU and the same would carried out shortly. Funding from PSDF would be sought

viii. . Conclusion in the OCC meetings are as follows:

(i) The States requiring funding from PSDF for SCADA up gradation to submit the DPR to NLDC. It is to be noted that in case PSDF funding is not sanctioned, states need to implement the scheme from their own resources.

(ii) This item would be discussed in details in the next TCC/SRPC meetings.

ix. AP SLDC vide letter dated 24.09.2021 addressed to PCD Division, CEA had requested to consider for allocation of entire project cost for establishment of Main SLDC and Backup SLDC (including the necessary civil works for Backup SLDC) including AMC through PSDF.


SRLDC/SLDCs may update the status/ members may deliberate.


O.4. Ensuring adequate availability of fuel for the coal based thermal power stations.

4.1 During the course of a review of the LGBR 2021-22 and in consideration of the fact that Southern Region will be countering its peak in the fourth quarter of 2021-22, Chairperson, CEA, has advised for following actions on the part of SRPC to ensure adequate availability of power:

a) Regular & continuous review of the anticipated power supply scenario with the concerned Central/State/Private sector utilities

b) Review of the fuel supply position for all the coal/lignite based thermal power stations supplying power in Southern Region, so as to ensure adequate fuel supply and no disruption in generation activity on account of fuel shortage. In this context, it has been expressed by Chairperson, CEA, that any problem envisaged on this account be promptly taken up with Fuel Management (FM) Division of CEA for timely intervention.

4.2 It may please be noted that SRLDC in consultation with the constituents has declared high demand season of SR and the months of February, March &April 2022 are under high demand season. The Coal/lignite based thermal stations of SR to ensure adequate fuel availability and no disruption in generation.

4.3 Agenda for Deliberation /Decision:

Action Plan by the Coal/lignite based thermal stations of SR to to ensure adequate fuel stock at the generating station.

O.5. Shifting of NLC TPS-II Unit-4 connected to 400 kV to 230 KV side

5.1 A Special Meeting was held on 28th May 2021 through Video Conferencing (VC) to discuss various Operational and Protection issues related to Tamil Nadu in which the issue of over loading of 400/230 kV 2X250 MVA ICTs at Neyveli Stage-II was discussed. In that meeting it was proposed that NLC TS II may explore the possibilities of shifting of NLC TPS II Unit-4 connectivity (or any other unit connected to 400 kV) to 230 kV side.

5.2 NLC TS-II had informed that shifting of Unit IV evacuation to 230 kV side is tedious job. A spare transformer needed to be looked into and also shut down of one station transformer is required which will add criticality to the station loads. The proposal may not be acceptable to NLCIL due to all these issues. TANTRANSCO was of the opinion that NLC TPS-II should explore the possibility of shifting NLC TS-II Unit-4 (any other Unit connected to 400 kV side) to 230 kV side, since the issues are mainly caused due to heavy injection from NLCIL complex, but not due to drawal issues by beneficiaries.

5.3 The issue was further discussed in the 180th OCC Meeting held on 09.07.2021 wherein it was decided that the proposal may be put up to TCC/SRPC.


Shifting of NLC TPS II Unit-4 connectivity (or any other unit connected to 400 kV) to 230 kV side


O.6. Utilization of inverters at Solar Parks in night mode for controlling high voltages

6.1. SRLDC had furnished a note on Reactive Power Capability of Invertors, its utilization and way forward for pilot project.

6.2. SRPC Secretariat had noted that all such pilot schemes in India are being implemented in consultation with NLDC and suggested that since the issue is not regional specific, NLDC may come up with a National perspective and requested SRLDC to arrange for views of NLDC on the notes for facilitating deliberation in SRPC forums.

6.3. NLDC vide letter dated 06.07.2020had informed as follows:

The operation of solar inverters in night mode for controlling high voltage appears a good initiative and would help the system reliability, In this regard, NLDC, would like to inform that similar usage of synchronous condenser mode of operation of hydro plants is being done in Northern Region since long at Tehri and Pong hydro generating plants. The arrangement for commercial settlement is based on an agreement at Regional Power Committee level. In this agreement, the active power which is consumed by the generating station for operation in synchronous condenser mode goes to the regional losses and plants do not have to incur deviation charges for the same. It is felt that similar mechanism for night mode operation of solar inverters could be agreed in SR also which will benefit entire system.

6.4. As decided in the In the 180th OCC Meeting held on 09.07.2021 the communications from NLDC along with SRLDC Note on the Reactive Power Capability of Invertors, its utilisation and way forward for pilot project had been made available to the constituents.

6.5. In the 180th OCC meeting it was decided to have special meeting to deliberate the proposal. Accordingly, a special Meeting was conducted on 27.07.2021 through video conferencing.

6.6. In the special meeting the following had been concluded:

1) Trial operation of solar inverters at Pavagada Solar Park (2050MW) in night mode (voltage control mode) for controlling high voltage to be implemented from 1st August 2021 for two months as pilot project.

2) The incremental power consumption by SPDs for voltage control mode operation would be treated as regional loss.

3) Incremental power consumption by SPDs would be arrived by reducing the bench mark APC.

4) Average block-wise APC of SPDs for the months of May 2021, June 2021 & July 2021 would be considered as block-wise bench mark APC.

5) KSPDCL to inform all the SPDs about the implementation of trial operation from 01.08.2021.

6) KSPDCL to coordinate with SPDs at Pavagada Solar Park for facilitating the voltage control mode operation of Inverters.

7) KSPDCL/SRLDC to ensure no commercial issues to be raised by SPDs in future on account of trial operation.

8) SRLDC to furnish the following data to SRPC secretariat on weekly basis:


(i) Actual SEM data at 220kV bus of PGCIL Pavagada PS end & 33/66kV bus at KSPDCL SS end.

(ii) Computed data after removing the incremental consumption of power from blocks/ substation at 220kV bus of PGCIL Pavagada PS end & 33/66kV bus at KSPDCL SS end.

9) SRLDC to share the updates/observations of the trial operation in monthly OCC meetings.

10) After completion of trial operation SRLDC to come up with detailed Report on trial operation of solar inverters at Pavagada Solar Park in night mode (voltage control mode) for controlling high voltages.

6.7. In the 182nd meeting of OCC (09.09.2021) the following had been concluded:

1) The trial operation of “Utilization of inverters at Solar Park in night mode for controlling high voltages” at Pavagada Solar Park shall be discontinued on 30th September 2021.

2) SRLDC may furnish a small note to CTUIL on the experience/lessen leaned from the trial operation to enable CTUIL to take up with SRPC (TP).

3) SRLDC would furnish detailed report on “Utilization of inverters at Solar Park in night mode for controlling high voltages” at Pavagada Solar Park.

4) SRLDC/SRPC may take up with CEA for Regulatory support to mandate the Night mode operation of Solar Inverters for voltage improvement.


i. SRLDC may share the experience of trial operation at Pavagada Solar Park.

ii. TCC/SRPC may decide the future course of action.

O.7. Implementation of the modified SPS scheme for Kaiga ICTs

7.1 Implementation of the modified SPS scheme at Kaiga end is as follows:

Stage-I Implemented

Stage-II Provision (Single ICT more than 500Mwe for 5 Seconds) made at Kaiga End – Respective implementation agency can extend the signal to Kadra and Kodasalli PH during ICT shut down condition.

Stage-III Implemented

7.2 In the 3rd meeting of Southern Regional Power Committee (Transmission Planning) the following had been noted during deliberation on ICT constraints of 400/220 kV 2x500 MVA ICTs at Kaiga:

CGM, SRLDC added that KPTCL has to implement SPS to avoid the tripping of ICTs at Kaiga S/s and subsequent tripping of generating units at Kaiga during contingencies. However, SPS has not yet been implemented. The implementation of modified SPS had been agreed in January, 2019.


Member (Power System), CEA, advised KPTCL to complete the reconductoring work at the earliest. He advised SRPC, to discuss and resolve the issues in implementation of SPS with KPTCL.

7.3 This issue had been discussed in OCC meetings. In the 184th meeting of OCC held on 10.11.2021, KPCL has informed that the SPS would be in place by the end of November 2021.


Implementation of the modified SPS scheme at Kaiga end by KPTCL/KPCL.

O.8. Up-gradation of existing RTUs / Gateways reporting to Ethernet on IEC 104 protocol

8.1 SRLDC had requested the Constituents in the 174th OCC Meeting to technically approve the up-gradation of 101 Protocol RTUs to 104 Protocol RTUs at the DCPC located Control Centers. The issue was being followed up in monthly OCC/COM SR Meetings.

8.2 In the COM SR Meeting held in February 2021 PGCIL had suggested that the state utilities may carry out migration wherever possible and states agreed to explore the possibility. PGCIL had requested to arrange recommendation by SRPC for migration of 101 protocol to 104 protocol wherever possible so that states can take up the migration. The up gradation of RTUs was under deliberation in COM SR & OCC meetings.

8.3 The status up-gradation of RTUs noted in the Meetings of OCC and COM SR are as follows:

Utility Total Protocol

Remarks Nos 101 104

APTRANSCO 313 114 199

Out of 149 RTUs (101) 62 Nos under up gradation, 37 Nos under replacement, 15 locations are not having OFC, take another one year for migration

KPTCL 1099 - 1099 All the RTUs are reporting on 104 protocols. SAS substations -75

KSEBL 63 38 25 Tender under evaluation. OPGW works under progress

TSTRANSCO 249 137 112

OPGW works were under progress up to 110 kV level and expected to be completed with 104 protocol RTUs under Reliable Communication Scheme within a period of 1 to 2 years with the support of funding from PSDF.


Puducherry 7 - 7 Upgraded to 104 protocol under reliable communication scheme-PSDF

TANTRANSCO

Most of the RTUs in their communication system were configured with 101 protocol with PLCC. However, OPGW works are under progress and up-gradation of RTUs & Control Centres are expected to be completed by the year 2023 with 104 protocol RTUs under Reliable Communication Scheme. Presently 25 RTUs are reporting on 104 protocol.

PGCIL

SR-I: 15 substations yet to be converted to 104 Protocol (Andhra Pradesh-7, Telangana-4, Karnataka-1, Generating

Stations-3) SR-II: 20 substations yet to be converted to 104 protocol (Karntataka-6,

Kerala-3, Tamil Nadu-11)

8.4 OCC recommended for migration of 101 protocol to 104 protocol wherever possible by the utilities. The recommendation would be put up to TCC/ SRPC.


i. Up-gradation of 101 Protocol RTUs to 104 Protocol RTUs by the constituents of SR.

ii. TCC/SRPC may approve the recommendation of OCC..

O.9. Constraints in export and import capability of Southern Region on account of Bus Split arrangement at 400 kV Raigarh PS

9.1 NLDC vide letter dated 21st October 2021 (Annexure-O.9.1) has informed that POSOCO will be proceeding with operationalisation of bus split arrangement at 400 kV Raigarh PS as approved in the 39th Standing Committee meeting of Western Region and requested by PGCIL vide letter dated 12.08.2021 in next 10-15 days.

9.2 NLDC has mentioned in that letter that the operation of bus split arrangement at 400 kV

Raigarh PS will reduce SR-WR and SR export transfer capability (TTC/ATC). The tentative reduction in TTC is as given below:

A. SR Export Scenario:


B. SR Import Scenario:

9.3 NLDC has requested that any other suggestion to avoid curtailment of transfer

capabilities or otherwise may please be communicated to NLDC.

9.4 This issue was discussed in the 184th meeting of OCC held on 10th November 2021.CTUIL has informed that they would revert back on the issue.


(i) CTUIL may suggest other options to avoid curtailment of transfer capability.

(ii) Operation plan to avoid curtailment of transfer capabilities.

O.10. Preparedness for cyclones/inclement weather condition during November December months

10.1 Agenda Proposed by SRLDC (Annexure-O.10.1): SRLDC has stated the

following:

(i). It was observed during past years, there was cyclonic conditions in November & December months. Hence, it is prudent to be in preparedness for handling such situations. All constituents are requested to take following measure in advance:

a) Emergency Restoration system (ERS) may made available at appropriate location near to coastal areas.

b) Sufficient spares for restoration may be identified and kept ready for relocating.

c) SLDCs are requested to keep Black start restoration procedures ready with real time grid operators.

d) Transmission line maintenance and vegetation management may be done in advance to avoid trippings.

(ii). In Southern Region, winter usually starts from November to mid-January, as a result substantial reduction of load would happen in these months and therefore low line loadings, high voltages etc. would be observed in the grid. Apart from this, fog during winter season pose challenges in grid Operation, some of the common challenges are given below:


a) High Variation in Peak and Off-Peak Demand

b) Morning & Evening peak steep ramp

c) High Voltage during off-peak hours

d) EHV line tripping during Fog/Smog

e) Load Crash events if any Utilities are requested to prepare plan for precautionary measures to be taken by them for carrying out pre-winter maintenance activities

(iii). Utilities are requested to prepare plan for precautionary measures to be taken by them for carrying out pre-winter maintenance activities


Plan for precautionary measures to be taken by them for carrying out pre-winter maintenance activities

O.11. TTC Declaration by SLDCs

11.1 Agenda Proposed by SRLDC ( refer Annexure-O.10.1) : SRLDC has stated

the following:

(i). As per CERC Regulations Measures to relieve congestion in real time operation - 2009, State Load Despatch Centre (SLDC) shall assess the Total Transfer Capability (TTC), Transmission Reliability Margin (TRM) and Available Transfer Capability (ATC) on its inter-State transmission corridor considering the meshed intra State corridors for exchange (import/ export) of power with inter-State Transmission System (ISTS).

(ii). In this regard, the constituents are requested to submit the PSS/E Base case of 4 different scenarios Peak: 1800 Hrs. Off-Peak: 0300 Hrs. Morning Peak: - 0900 Hrs. Solar Peak: 1300 Hrs. for the upcoming 4th month by 20th of every month to enable RLDC to determine the Margin for STOA and declare TTC by 26thof every month.

(iii). At present Andhra Pradesh, Telangana and Tamil Nadu has calculated and furnished its TTC declaration details to SRLDC but yet to declare in website. Karnataka is yet to submit the TTC details. Present TTC details (calculated from the latest PSS/E peak case of February 2022) along with limiting constraints are at Annexure O.10.1 item No.ii.

(iv). All constituents are requested to declare the TTC/ATC of respective control area on their website and plan necessary augmentation to relive the constraints


i. Submission of the PSS/E Base case by SLDCs to SRLDC

ii. TTC declaration by SLDCs and posting at website.


O.12. Compliance of CEA connectivity regulation for Renewable Energy Generators

12.1 Agenda Proposed by SRLDC (refer Annexure-O.10.1): SRLDC has stated the following:

(i). Due to high renewable energy penetration in Southern, it is important that existing Renewable Energy Generator’s which are displacing the conventional synchronous machines also to support and provide the various Grid Support services. The Central Electricity Authority (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 was notified on 6thFebruary2019.

(ii). The Compliance to these regulations (Amendments) by RE generators is to be monitored at regional and state level. SLDCs to apprise the status of compliance of CEA Regulations (Relevant clauses in the regulation quoted by SRLDC refer Annexure-O.10.1 item No.iii).


i. Monitoring of Compliance of CEA (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019 by RE generators at regional and state level.

ii. SLDCs to apprise the status of compliance.

O.13. Improvement in Transmission Outage Planning


(i). In Southern Region the Outages are being approved considering after detailed deliberation among the participants in VC keeping in view technical factors like, availability of corridor, loading of corridors, N-1 criteria etc. The outage planning is being done for Calendar Month ahead with two opportunities.

a) Main OCC Meeting: Meeting is conducted a day ahead prior to the Main OCC in Video Conference mode and all the transmission element outages are approved after detailed deliberation with constituents, SRPC & SRLDC

b) Mid Review Meeting: A second opportunity is being provided around 25th of the current month to propose outages for the next calendar month. This is being done to facilitate/accommodate the changes due to on-site difficulties & under-construction activities

(ii). Despite the above two opportunities it is observed that constituents are requesting many unplanned outages in PNOCC (106 Nos) & Emergency category (325 Nos). Many outages despite being approved are not being availed by constituents due to several reason which affects the outage planning. Hence, the constituents are requested for improvement in outage planning with healthy maintenance practises and minimising the Unplanned & Emergency outages.



Improvement in outage planning with healthy maintenance practises and minimising the Unplanned & Emergency outages.

O.14. High-Voltage scenario in Southern Region


(i). During off-peak season in Southern region, sever high voltage scenario is experienced with voltages greater than 420kV for 100% of time in a day. Additionally, to minimize the over-voltage tripping many transmission lines are opened/kept open continuously for prolonged duration further reducing the reliability & strength of the system. To mitigate this many bus reactors have been planned and approved in the previous standing committee but have not yet been commissioned, the issue was taken up in 179th OCCM for follow up.

(ii). The commissioning of these planned Bus-Reactor’s would help in maintaining a better voltage profile and result in loss minimization. The Entities may update the forum regarding the commissioning of the bus reactor’s. (refer Annexure-O.10.1 for the list of stations the High voltage scenario observed during 2020-21 and the list of planned reactors)


i. Action taken by the utilities to mitigate high voltage issues.

ii. Status of commissioning of the planned Reactors by the utilities.

O.15. ICT Over-Loading


(i). The following are highly over-loaded ICTs:

a. 400/230kV Neyvelli TS2 ICT: 400/230kV Neyvelli TS2 ICTs(2x250 MVA) are severely loaded by 230 MW each and N-1 violation of these ICT is for considerable amount of time. Any tripping of theses ICTs will lead to a cascade tripping and cause a local disturbance. At present network re-arrangement of line opening and network splitting at Neyvelli area is done and ICT loading is reduced. The already planned station of 400/230kV Cuddalore SS & 400/230kV Ariyalur SS, would relive this ICT and provide reliable supply to Cuddalore area.

b. 400/220kV Kaiga ICT: During Units availability at KaigaGS U-1& 2 and full generation at Kadra&Kodasalli HEP , the 2x500 MVA ICTs are loaded beyond their N-1 limits . This is due to opening of 220kV Nagjheri – Kodasalli D/C which is done to relive 220kV line loadings beyond Nagjheri – Ambewadi – Narendra sections. The


Upgradation of this network to HTLS has been approved in standing committee. KPTCL may expedite the upgradation and update the forum with details

(ii). The ICT N-1 violation observed during 2020 -21 is given below:

S.NO Station Name Q1 Q2 Q3 Q4

ICTs violating N-1 limit in % of time 1 400/220 kV 2X315 MVA ICTs at Narnoor 0 0 0 13 2 400/220 kV 3X315 MVA ICTs at Nellore 3 0 0 0 3 400/220 kV 3X315 MVA ICTs at Vemagiri 5 1 0 19 4 400/220kV 2X315+2X250 MVA ICTs at Ramagundam 0 0 0 17 5 765/400kV 2X1500MVA ICTs at Nizamabad 0 0 0 0 6 400/220 kV 2X315 MVA ICTs at UPCL 8 0 0 23 7 400/220 kV 2X315+1X500 MVA ICTs at Mysore 10 0 2 46 8 400/220 kV 2X500 MVA ICTs at Kaiga 11 49 23 16 9 400/220 kV 2X500 MVA ICTs at Kolar 3 0 1 14 10 400/220 kV 2X500 MVA ICTs at Narendra 2 0 0 3 11 400/220 kV 3X500 MVA ICTs at Hoody 2 6 5 0 12 400/220 kV 3X500 MVA ICTs at Nelamangala 0 1 4 13 13 400/220kV 2X315 MVA ICTs at Hassan 0 0 0 4 14 400/220kV 3X500MVA ICTs at Somanahalli 0 0 0 2 15 400/220kV 3X315 MVA ICTs at Hosur 0 0 0 0 16 400/230 kV 2X250 MVA ICTs at NLC TS2 0 0 0 13 17 400/230 kV 2X315 MVA ICTs at Thiruvalam 0 0 0 1 18 400/220 kV 2X315 MVA ICTs at Kochi 23 0 0 1


i. Status of commission of 400/230kV Cuddalore SS & 400/230kV Ariyalur SS

ii. Status of Upgradation of the 220 kV network (KPTCL) to HTLS approved in standing committee

O.16. Prolonged outage of transmission elements as on 09-11-2021


(i). The following transmission elements are under prolonged outage in Southern Grid. Constituents are requested to revive these elements at the earliest.

a) 400kV Srisailam_left_bank-Sattenapalli-1 is out since 20th August 2020. Line due to fire incident at Srisailam

b) 400kV Nelamangala-Hassan line is out since 4th October 2021. Line had tripped on R-N fault. Tower cross arm to be replaced.

c) 400kV/230kV Karamadai-ICT-3 out since 15th May 2021 due to OLTC oil leakage

d) 400KV/230KV KAYATHAR-ICT-3 out since 20th February 2020

e) 400kV Kudankulam B/R-2 out since 14th December 2016.


Revival of transmission lines under prolonged outage.


O.17. Status of hydro units not available for Pump mode Operation as on 09- 11-2021 as provided by SLDC's


Tamil Nadu -Kadampari Unit-1,2 & 4 : not available for pump operation

Telanagana-SSLM LBPH Units (1to 6) : No pump and condenser operation after fire incident at Srisailam on 20- 8-2020

SLDCs are requested to coordinate with the Generating Stations for keeping the Units ready for pump mode operation at the earliest.


Action Plan of Tamil Nadu and Telangana for keeping the units ready for pump mode operation.

O.18. Status of hydro units not available for Condenser mode Operation as on 09- 11-2021 as provided by SLDC's


(i). Operation of hydro units in condenser mode wherever possible would help in combating high voltages in the grid during low demand conditions. Constituents informed that the following hydro stations have the condenser provision (some units with few modifications) but as on date few units at Nagarjuna Sagar only being operated in condenser mode.

(ii). SLDCs are requested to coordinate with the Generating Stations for keeping the Units ready for condenser mode operation at the earliest.


Action Plan of Tamil Nadu, Karnataka, Kerala and Telangana for keeping the units ready for condenser mode operation.

O.19. Mitigation of reduction/no change in TTC after commissioning of HVDC System – Meeting summer demand of Kerala.

19.1 Agenda Proposed by KSEBL (Annexure-O.19.1): KSEBL has stated the

following:

(i). With the commissioning of 2000MW HVDC terminal at North Thrissur as per the joint study in 2020, Kochi ICT was found to be the limiting constraints for the ATC of Kerala.


(ii). Proposal of 3rd ICT at Kochi Substation was already approved in the 2nd SRPCTP meeting held on 01.10.2020 and is in the processing stage. However, for meeting the summer demand, the ATC (import capability) of Kerala could be constraint. The ICT procured and installed by PGCIL may not be available in this time frame.

(iii). Hence, as an interim arrangement, KSEBL had requested that one of the regional spare ICTs may be commissioned at Kochi Substation as early as possible, in any case by December 2021-January 2022.

(iv). The committee may concur utilization of spare ICT at Kochi Substation till the commissioning of new ICT as a special case considering the fact that, without this transformer Kerala may face constraints in meeting the summer demand due to the N-1 violation of Kochi ICT consequent to the commissioning of HVDC System in spite of meeting the expenditure for the HVDC system.


Utilization of SR spare ICT at Kochi till the commissioning of new ICT.

O.20. Proposal for 110kV Substation at Vattalakki, Palakkad.

20.1 Agenda Proposed by KSEBL (refer Annexure-O.19.1): KSEBL has stated the following:

(i). To improve the power reliability at Agaly area in Palakkad district during natural calamity and as per the directions of the District Administration of Palakkad, KSEBL proposed to construct a new 110kV Substation at Vattalakki near Kottathara, Palakkad and 110kV DC line from Somayanur near Coimbatore, Tamilnadu. As per preliminary investigations, it is inferred that 110kV supply can be tapped from tower No.28 of 110kV Thudiyallur - OKM Mills Pakuthi feeder of TANTRANSCO coming from 220kV Substation Thudiyallur, which is fed from 400kV Substation, Karamadai. This tower No.28 is situated at Somayanur, Coimbatore district near Anakkatty - Coimbatore road.

(ii). It is required to collect the technical particulars and other requisite details for conducting a Load Flow Study (LFS) and feasibility study. Since the proposed project is an interstate one, TANTRANSCO also has to approve the proposal, and then only KSEBL can go ahead with the project. Hence, it is requested to take up the matter for giving necessary directions to TANTRANSCO for cooperating with KSEBL for initiating a joint study for the project.


i. Concurrence of TANTRANSCO for the KSEBL proposal to construct a new 110kV Substation at Vattalakki.

ii. Joint study by KSEBL and TANTRANSCO.


O.21. Enhancing the power import to Kerala through 110 kV Konaje – Manjeswaram interstate Line

21.1 Agenda Proposed by KSEBL (refer Annexure-O.19.1): KSEBL has stated the following:

The Power import to Kerala through the 110 kV Konaje – Manjeswaram interstate line is to be enhanced. The power import at present is just to the tune of 22MW which is even much lower at many times. Enhancing the import is essential to resolve the power crisis in Kasaragode district.


i. Enhancing the power import by Kerala through 110 kV Konaje- Manjeeswaram line

ii. Concurrence of KPTCL & SRLDC.

O.22. Strenthening of 110 kV Konaje – Manjeswaram interstate Line (Karnataka Portion)

22.1 Agenda Proposed by KPTCL (refer Annexure-O.19.1): KPTCL has stated the following:

(i). In the SRPC meeting held on 13.7.2012, KSEB has agreed in principle to bear the entire cost of new DC line which would be executed by KPTCL in Karnataka jurisdiction till Thoudgoli limits (Kerala state border).

(ii). Executive Engineer, Transmission Division Kasargod, KSEB had requested to furnish the estimate for reconstruction of SC line on DC tower in the existing corridor of SC 110 kv Konaje-Manjeshwaram line for a distance of 5.5 km from 110 kV Konaje Station to Thougodugoli limits vide their letter No.TD/KSGD/Upgradation/2012-13/778 dt.7.9.2012. The estimate amounting to Rs.2,21,50,000.00 was prepared and submitted to KSEB, Kasargod for further process.

(iii). However, no further response was obtained from KSEB about the progress of work of placing a new DC line in Karnataka jurisdiction even after repeated correspondence by Chief Engineer (El), Transmission Zone, Hassan, KPTCL and Superintending Engineer (El), W&M Circle, KPTCL, Mangalore.

(iv). Already KSEB has strengthened the same line in their jurisdiction by replacing all H-frame towers by DC towers leaving behind the KPTCL portion.


(v). The present condition of the tower structure of the said bit is very pathetic & in hazardous condition and needs early action to undertake line strengthening works since the line is in dilapidated state.


Strengthening of 110 kV Konaje- Manjeeswaram line for a distance of 5.5 km from 110 kV Konaje Station to Thougodugoli.

O.23. Re-Construction of dilapidated Townships of Kadapa and Vijayawada Substations under Additional Capitalization block 2019-24

23.1 Agenda Proposed by PGCIL (refer Annexure-O.1.8): PGCIL has stated the following:

(i). 400/220kV Substation at Kadapa SS was commissioned under RSTPP Stage – I during 1985 and Vijayawada was commissioned under CTP Project during 1991. Kadapa and Vijaywada stations are critical stations of Southern Region, feeding power to state of Andhra Pradesh, Tamilnadu & Karnataka.

(ii). Structural assessment of the buildings through M/s NCCBM (National council for cement and building material, Govt. of India, Hyderabad) has been carried out. The report is awaited and will be submitted shortly.

(iii). For meeting the basic minimum requirement for continuous manning and safety of the manpower of these stations, re-construction of damaged residential quarters is proposed at Kadapa and Vijayawada, under the provisions of Additional Capitalization for the tariff period 2019-24 at an estimated cost of Rs. 8.50 Crores


Consent of constituents for re-construction of damaged residential quarters at Kadapa and Vijayawada, under the provisions of Additional Capitalization for the tariff period 2019-24 at an estimated cost of Rs. 8.50 Crores.

O.24. Up gradation of 63MVAR Bus Reactors of Gooty and Gajuwaka with 125MVAR under Additional Capitalization for the tariff block 2019-24


(i). Gooty and Gajuwaka substations of POWERGRID are important stations of Southern Region. The LV test/oil test report of 420kV, 63 MVAR Bus Reactor at Gooty & 420kV, 50 MVAR Bus Reactor at Gajuwaka indicate problem in the reactors. Residual life assessment of the said reactors was carried out through CPRI and they have recommended for replacement of these reactors (M/s CPRI recommendation is attached for kind reference). Both the reactors have completed their useful life (25 years as per CERC regulation)


(ii). POWERGRID’s Submission: Considering the high voltage profile at these stations, it is pertinent to replace these reactors with 125 MVAR reactors. As such cost wise, there will not be much difference between 50/63 MVAR and 125 MVAR reactors. Based on above it is proposed to replace 50 MVAR & 63 MVAR Bus Reactors at Vizag and Gooty substations respectively with 125 MVAR Bus Reactors.


Replace/up-gradation 50 MVAR & 63 MVAR Bus Reactors at Gazuwaka and Gooty substations respectively with 125 MVAR Bus Reactors under additional capitalization for the tariff period 2019-24.

O.25. Stress on EHV equipment due to High System Voltage


This has reference to sustained over voltages of 765kV and 400kV elements due to over voltage in the system, specifically at 765kV Kadapa GIS, 765 kV Vemagiri GIS, 765 kV Nizamabad GIS and 400kV Nellore & Khammam Substations. Voltage profile attached. The issue was discussed in Special Meetings arranged by SRPC with TSTRANSCO and APTRANSCO on 05.10.2020 and 20.11.2020 respectively. Due to High Voltage in the system, useful life of EHV equipment is adversely affected due to the stress from High System Voltage and switching surges in each operation. Recently, 04 Nos. of Lighting Arrestors (02 Nos. each at 765kV Chilakaluripeta and 400kV Nellore Substations) failed due to High System Voltage stress (beyond IEGC and equipment rating) and switching surges. In case of Kadapa, Vemagiri and Nizamabad stations, GIS equipment are provided as terminal equipment and these are sensitive and vulnerable to Voltage stress and switching surges. Any failure in GIS system is very costly and may result in prolonged outage which involves imported spares / overseas manufacturer etc.


i. Possibility of providing VAR compensation / STATCOM at few of these stations.

ii. Regulation of Voltage profile as per IEGC (at voltage below rated voltage of equipment).

iii. Optimization of no of circuit breaker switching operations

O.26. Continuation of the use of Kurnool Line Reactors as Bus Reactors, as per CERC Order in petition No. 248/TT/2019

26.1 Item Proposed by PGCIL (refer Annexure-O.1.8): PGCIL has stated the following:


(i). POWERGRID has implemented bay extension works at Kurnool, Maheshwaram & Warangal for termination of TBCB Lines under the scope of M/s WKTL (TBCB Licensee). Though the implementation of lines was delayed, POWERGRID has made ready the bays as per the scheduled COD i.e., 09.11.2019. Further, in the case of Kurnool Bay extension works, SRPC forum in 35th SRPC Meeting held on 02.02.2019, approved for early commissioning of reactors and using them as Bus Reactors instead of Line Reactors, so as to reduce voltages of 765kV & 400kV Nodes at Kurnool. Accordingly, the Kurnool Bay extension works were declared under commercial operation w.e.f 11.03.2019.

(ii). CERC has passed Tariff Order in Petition No: 248/TT/2019, wherein CERC has approved the COD as 11.03.2019. As the associated lines under the scope of M/s WKTL (TBCB Licensee) have not been made ready, CERC directed POWERGRID to approach RPC forum for continuing to the use the line reactor as bus reactor post scheduled COD (09.11.2019) and also, regarding the sharing of transmission charges beyond scheduled COD.

(iii). The Reactors may be continued to use as bus reactors. Further, in regards to sharing of Transmission Charges, since the reactors are being used as Bus Reactors benefitting the grid as a whole, it is proposed that the transmission charges pertaining to the above reactors may be shared with all the constituents of the southern region.

26.2 SRPC (TP) in its 3rd meeting (24.08.20210) has agreed the proposal of using 2x240 MVAR switchable line reactors at Kurnool 765kV S/s as bus reactor till commissioning of Hyderabad– Kurnool 765kV D/c line.


i) Continuation of the use of Kurnool line Reactors as bus reactors.

ii) Sharing of the transmission charges pertaining to the above reactors.

(ii) Commercial

C.1 Settlement of Wheeling Charges paid mutually with effect from July 2011 to March 2018

1.1 Proposed by: KSEBL vide letter dated 22.07.2020(refer Annexure-O.19.1)

Background:

CERC Orders (in KPTCL- Petition No.225/TT/2013, KSEB- Petition No. 232/TT/2013 and TNEB- Petition No.212/TT/2013), mention that the YTC for the interstate lines have been taken in line with Sharing of Inter-State Transmission Charges and Losses Regulations, 2010 and the charges reimbursable had been calculated from 1.7.2011. The Wheeling charges indicated at 3(b) of the REA issued from the month of July 2011 were provisional and issued as inputs from NLDC were pending. As these lines are to be covered under PoC Mechanism from 1.7.2011, the Wheeling charges indicated at 3(b) of the REA issued from the month of


July 2011 ceased to have any commercial implications. SRPC vide letter dated 17.3.2017 had requested the Constituents to mutually settle Wheeling Charge payment effected from July, 2011. SRPC vide letter No: SRPC/SE-I/2018/7126-36 dated 06.11.2018 had also circulated the final statements.

1.2 The issue was under deliberation in various Commercial Sub-Committee meetings of SRPC. In the 38th SRPC Meeting (23.12.2020), PCKL/ KPTCL & APPCC were requested to settle the pending dues. The status of payments to be made as noted in the Commercial Sub-Committee meetings is as below:

Payable by Payable to Amount Remarks

APPCC/

APTRANSCO/ TSTRANSCO

TANGEDCO Rs. 25 lakhs 49th CCM(03.09.2021):

AP and Telangana to reconcile their shares of payment (out of Rs. 25 lakhs) to Tamil Nadu mutually within 15 days.

KPTCL/PCKL

TANGEDCO Rs.7.69 Crores

38th SRPC(23.12.2021)

PCKL to comply with the commitment given in the TCC (to arrange high level meeting within 15 days between PCKL/KPTCL and KSEBL).

49th CCM (03.09.2021):

KPTCL: Final approval of the bills was awaited from the Management for payments to TANGEDCO (Rs. 7.69 Crores), TSTRANSCO (Rs. 9.17 Crores) & Goa (Rs. 16.74 Crores). Subsequent to the approval, the funds are to be allocated from the financial wing. Thereafter, the dues will be settled. The dues of KSEBL are handled by PCKL.

PCKL: A letter was addressed to KPTCL in this regard. They are taking up the matter to MD, KPTCL. PCKL assured to arrange a meeting within a fortnight for detailed discussion with KSEBL.

KSEBL Rs.12.76 Crores

(July 2011 to August 2016)

TSTRANSCO

Rs. 9.33 Crores

(July 2011 to October 2016)

Goa Rs. 16.74 Crores

Issue:

Wheeling charges for wheeling of CGS, MAPS and Kaiga power using interstate lines are shown usually in the Regional Energy Account statement published by SRPC. Based on that, transmission and wheeling charges are claimed by KPTCL and TNEB which are to be paid by KSEBL. KSEBL has paid the transmission and wheeling charges till May 2016. As these lines are to be covered under PoC mechanism from 01.07.2011 as per the CERC tariff orders, PGCIL collected transmission charges from KSEBL for the above period and issued to KPTCL


and TNEB. Thus there is double receipt by TNEB & KPTCL for the same claim. Thus, the transmission and wheeling charges paid to TNEB and KPTCL from July 2011 onwards are to be refunded to KSEBL. TNEB has already refunded the amount of Rs.2.34 Crore on 14.05.2019. But KPTCL has not yet refunded.

The pending payment issues between PCKL/KPTCL which are being deliberated in several Fora of SRPC since 2012. An amount of Rs.12.76 Cr with interest is receivable to KSEBL from PCKL/KPTCL towards the reimbursement of Transmission & Wheeling charges w.e.f. 07/2011. Now, KPTCL vide letter dated 03.07.2021(Annexure-C.1.2) has come up with a

stand that the amount is not reimbursable to KSEBL, since KPTCL is not agreeing to the Compensation for Frequency Linked Penalty Scheme for under/over drawal by Karnataka during the period 04/1994 to 05/1997 of Rs.11.58 Crores already adjusted by KSEBL in the settlement dated 18/08/2016. Hence KSEBL strongly object the stand of KPTCL that the Frequency Linked Penalty Scheme was never mutually agreed upon by all the constituents and the Scheme was beyond the powers of SREB.

The repeated denying of the already settled facts and figures by M/s PCKL/KPTCL would only lead to inordinate delay in realizing KSEBL’s claims involving considerable amount and human resource. Hence, it is requested that the non-refund of transmission and wheeling charges reimbursable to KSEBL with interest may be taken up and to settle this long pending issue in this SRPC meeting itself.


C.2 Outstanding Dues by Distribution Utilities of SR to PTCIL

2.1 Proposed by: PTCIL vide letter dated 08.11.2021(Annexure-C.2.1)

Issue:

Major outstanding dues by distribution utilities of SR to PTCIL are as below:

Figures in Rs. Crores Sl. No.

State Utility/DISCOM

Principal Outstanding

Surcharge Total

Details

1 TSPCC 460.03 20.50 480.53 Medium term power Supply from RK Power Gen Pvt. Ltd under Pilot Scheme-I since September 2020

2 TANGEDCO 457.59 99.11 556.70 Medium term power Supply from IL&FS Tamil Nadu under Pilot Scheme-I since February 2021

3 APPCC 47.57 47.57 Outstanding surcharge amount: of Pre-bifurcation period (before 01.06.2014)- Rs 32.97 cr.

Post-bifurcation period (after 01.06.2014)- Rs 14.6 cr.


PTC has been making regular follow-ups with the above utilities through emails, telephone and visit to utilities. PTCIL requests that DISCOMs commit the date for payment of outstanding dues.


C.3 Poor Realization of Power Dues from DISCOMs

3.1 Proposed by: NTPL vide letter dated 08.11.2021(Annexure-C.3.1)

Issue:

Outstanding power dues (>45 days) as on 08.11.2021 from DISCOMs to NTPL are as below:

Sl.No. DISCOM Dues>45days (Rs. Crores)

1 APCPDCL 13.67 2 APEPDCL 19.02 3 APSPDCL 19.50 4 BESCOM 4.11 5 CESC 35.76 6 GESCOM 32.89 7 HESCOM 24.35 8 TANGEDCO 146.06 9 TSNPDCL 73.23 10 TSSPDCL 167.88

Total 536.45

The delay in settlement of power bills is severely affecting the working capital fund of the company including coal purchase. The delay in settlement of bills also causes financial strain to meet operational, capital expenditure requirements, repayment schedule of borrowings and it attracts adverse observations from regulators, auditors and DPE.

DISCOMs may be requested to settle the outstanding dues at the earliest.


C.4 Refusal of NPCIL for deferment of Capacity Charges for unscheduled power during the COVID Lockdown Period and reduction of rate of Late Payment Surcharge as directed by MoP

4.1 TANGEDCO vide letter dated 19.05.2021 has submitted that MoP in circular dated 16.05.2020 had stated that under the Atmanirbhar Bharat, special economic and comprehensive package has been considered including the liquidity infusion by PFC/REC of Rs.90,000 Crore to DISCOMs against receivables and loans to be given against State guarantees for exclusive purpose of discharging liabilities of DISCOMs to power Generating companies (Gencos). Further, rebate to DISCOMs for the lockdown period on account of COVID-19 pandemic by Central Public Sector Generation Companies/ PGCIL was also announced as below:


1) Deferment of capacity charges for power not scheduled, to be payable without interest after the end of the lockdown period in three equal monthly instalments.

2) Rebate of about 20-25% on power supply billed (fixed cost) to Discoms and interstate transmission charges levied by PGCIL

Further, in the instructions dated 20.08.2020, the MoP had directed that the rate of Late Payment Surcharge shall not exceed 1% per month for all payments made under Liquidity infusion scheme of PFC and REC under Atmanirbhar Bharat.

4.2 The issue was deliberated in the 46th, 47th meetings of Commercial Sub-Committee wherein NPCIL stations were requested to take up with their Corporate for early decision in this regard and requested to pass on the COVID rebate as per the above instructions to help TANGEDCO to sail out of the extreme financial crisis being faced and due to the fact that whatever the benefits the Genco’s are providing to Discoms, will eventually be passed to the consumers.

4.3 The issue was further deliberated in the 48th meeting of Commercial Sub-Committee held on 27.05.2021, the following were noted/deliberated:

a) It was noted that NPCIL HQ has not responded to the letters of TANGEDCO regarding the implementation of MoP circular dated 16.05.2020 which is a cause of concern.

b) KKNPP had informed that Rebate of about 20-25% on power supply billed (fixed cost) to DISCOMs, the rebate is applicable only for the two-part tariff Generators whereas NPCIL stations are of single-part tariff. KKNPP had requested to release outstanding payments so that they would be able to take up with their NPCIL Headquarters.

c) TANGEDCO had informed that even though NPCIL generators are of single-part tariff, there are few basic components in the tariff which could be categorized as the components used to arrive the fixed cost.

d) APPCC/PCKL/KSEBL/TSPCC/PED had confirmed that they also did not receive any rebate from NPCIL stations as per the MoP circular dated 16.05.2020.

e) MS, SRPC had stated Ministry of Power has announced the scheme for relieving the financial stress of the DISCOMs on account of COVID-19 pandemic. In view of the objectives envisaged in the scheme, NPCIL Stations should consider the relief measures announced to DISCOMs in the scheme and the same would be passed on to the DISCOMs positively.

f) After deliberation, in view of the concerns raised by the beneficiaries of NPCIL stations, it was decided that SRPC secretariat may take up the issue with NPCIL Headquarters for implementing the MoP circular dated 16.05.2020 by NPCIL stations.

4.4 As decided in the 48th meeting of Commercial Sub-Committee (27.05.2021), MS, SRPC vide letter dated 04.06.2021 (Annexure- C.4.4) had taken up with NPCIL HQ.

4.5 In the 49th meeting of Commercial Sub-Committee (03.09.2021), the matter was deliberated and Commercial sub-committee had recommended to put up this issue for the upcoming

TCC/SRPC meetings.



C.5 Issues Regarding Calculation of Inter State Transmission Charges for TANGEDCO by NLDC

5.1 Central Transmission Utility of India Limited (CTUIL) vide letter dated 24th September 2021 had intimated that they were in receipt of letter from MoP dated 17.09.2021 enclosing D.O letter dated 21.08.2021 from TANGEDCO regarding computation of ISTS charges for TANGEDCO by NLDC and requested that a special SRPC meeting may be convened to deliberate on the issues raised by TANGEDCO with respect to MAPS, NLC TS- II, Kudankulam NPP and NTECL Vallur. In this regard, a copy of CMD, TANGEDCO letter dated 07.10.2021 with request to convene a meeting with all stakeholders had been received.

5.2 A Special Meeting of TCC was held on 18th October 2021 through VC to discuss on the issues raised by TANGEDCO w.r.t. sharing of ISTS charges/computation of LTA of the central generating stations located in Tamil Nadu (MoM is at Annexure- C.5.2) wherein it

was decided that a Sub-Group would be formed under SRPC Secretariat with representatives from CTUIL, NLDC, SRLDC and SLDCs of SR to formulate an Objective Methodology/ General Philosophy to be adopted for determining LTA/MTOA corresponding to capacity connected to ISTS in case of Generating Stations connected to both ISTS and intra-State transmission system and submit its recommendations to TCC within one month.

5.3 Accordingly, a Sub-Group (LTA-Sub Group) comprising the Members from CTUIL, NLDC, SRLDC and SLDCs/STUs of Southern Region has been constituted. So far, LTA-Sub Group has conducted one meeting and a joint study meeting.


C.6 KSEBL Agenda Items for Update

Proposed by: KSEBL vide letter dated 22.07.2021(refer Annexure-O.19.1 )

6.1 DAE Tariff notification of Kudankulam Station

6.1.1 The Department of Atomic Energy (DAE) has not released the tariff notification of Kudankulam Nuclear Power Plant of NPCIL. The bills are being raised with provisional tariff, as per Clause 7.4 of the PPA. Hence the supplementary bills such as tax on Return on Equity due to revision of tax rate etc. could not be admitted.

6.1.2 In 39th TCC Meeting held on 22.12.2020, NPCIL had stated that the concern of KSEBL would be taken up appropriately for the needful.

NPCIL may update

6.2 Transmission charges / sharing related issues

Background:

a) Subsequent to 37th Meeting of SRPC (01.02.2020), Chairperson, SRPC vide letter dated 02.06.2020 had taken up the issue with Secretary(P) to declare Raigarh (Chhatisgarh)-


Pugalur (TN) HVDC & Pugalur (TN) – Trissur (KER) HVDC system as national and strategic projects and the cost could be shared by all the DICs.

b) In 37th meeting of TCC (28.10.2020), the forum had agreed in principle for declaring the whole assets of Raigarh (Chhatisgarh)-Pugalur (TN) HVDC & Pugalur (TN) – Trissur (KER) HVDC system as national and strategic projects/components and accordingly CERC may be approached.

c) In 38th Meeting of TCC (22.12.2020), all the states had requested CTU to come up with action plan for beneficial utilization of the corridor without any additional investment for export of surplus power. CTU and POSOCO may recommend to CERC for considering the entire HVDC system under national component.

d) In 38th Meeting of SRPC (23.12.2020), Chairperson, SRPC had stated that Raigarh (Chhatisgarh)-Pugalur (TN) HVDC & Pugalur (TN) – Trissur (KER) HVDC would affect all the SR constituents, as per the new transmission charges sharing regulations the liability of each state is going up. If this asset is treated as regional asset, burden on SR constituents would increase. As recommended by TCC, the entire HVDC system needed to be declared as strategic projects/components and national component. Apart from Chairperson, SRPC taking up, all the states also may take up with CERC individually.

e) Subsequently, Chairperson, SRPC had taken up with MoP/CERC as follows: (Copy of the letters refer Annexure-ATR-3)

i) Letter dated 07.01.2021 with Secretary (P) to consider the request of SR constituents to declare Raigarh (Chhatisgarh)-Pugalur (TN) HVDC & Pugalur (TN) – Trissur (KER) HVDC system as national and strategic projects and the cost could be shared by all the DICs.

ii) Letter dated 07.01.2021 with Chairperson, CERC to consider the request of SR constituents to include Raigarh (Chhatisgarh)-Pugalur (TN) HVDC & Pugalur (TN) – Trissur (KER) HVDC under National Component (NC) and share 100% of the transmission charges of this HVDC links under National Component as it will benefit the states/stakeholders across the country.

iii) Letter dated 22.03.2021 with Chairperson, CERC upon receipt of the reply from MoP for the Chairperson, SRPC letter dated 07.01.2021 in which MoP has stated that the sharing of ISTS charges is a Regulatory issue and within the jurisdiction of CERC.

Issue:

The 37th TCC, forum agreed in principle for declaring the whole assets of Raigarh (Chhatisgarh)-Pugalur (TN) HVDC & Pugalur (TN) – Thrissur (KER) HVDC system as national and strategic projects/components. SRPC may follow up with MoP/CERC in this regard. In the TCC meeting it was also suggested that PGCIL could request CERC in this respect while filing tariff petition for the assets.

TSTRANSCO vide letter dated 23.07.2021(Annexure- C.6.2) has requested that on behalf of

all the constituents of SRPC, SRPC to take up with Hon’ble CERC and MoP for declaring the


assets of HVDC Raigarh(Chattigarh)- Pugalur(TN)-Trissur (Kerala) as part of national components in similar lines to Biswanath-Chariali/Alipurdwar to Agra HVDC system.

PGCIL/CTU may update / This may please be deliberated.

C.7 Accounting of drawal/deviation by Nuclear Stations/Units:

A. Negative DC punching by NPCIL Stations/Units during drawal period

i) In the 47th Meeting of Commercial Sub-Committee held on 24.02.2021, KSEBL had stated that the post-facto component of DSM may be imposed on the beneficiaries only when the nuclear units are running. Since nuclear stations do not come under the purview of ABT, when the units under shut down, the energy drawn by the nuclear stations can be settled through REA bills and need not be settled in DSM. SRPC secretariat had pointed out that the energy injected to the grid and energy consumed from the grid needed to be balanced for proper energy accounting, hence the energy drawn by the nuclear stations/units from the grid, under shut down also to be accounted. As per the provision of PPA between NPCIL Stations and beneficiaries, the auxiliary power requirements of the plant as and when required shall be made available by the beneficiaries. Prevailing methodology for drawal by nuclear generating stations was finalized after extensive deliberations with stake holders in line with the provisions of PPA and is being followed since 2003. After deliberations, it was suggested that KSBEL may propose methodology for accounting of drawal of nuclear stations in order to review the existing methodology.

ii) Subsequently, KSEBL vide letter dated 09.03.2021 had proposed the options/remedial measures in this regard. A special meeting on post-facto adjustment/accounting of drawals of nuclear stations was held on 28.04.2021(Record notes are at Annexure-C.7.A.ii) and the

following were agreed:

a) SRLDC to implement the provision of punching negative DC by the NPCIL stations/units during drawal scenarios in their scheduling software at the earliest.

b) NPCIL stations/units to ensure punching of realistic negative DC based on the drawal pattern/auxiliary requirement when the station/unit under shutdown. Deviation by the generator would be computed with reference to the negative DC punched.

c) NPCIL stations to revise the DC immediately (possibly within the next time block) in case of tripping of unit/reduction in generation. NPCIL stations/units to ensure punching of DC/revision of DC closer to actual injection/drawal pattern.

iii) In 49th Meeting of Commercial Sub-Committee held on 03.09.2021 the following were noted/deliberated:

a) In 48th Meeting of Commercial Sub-Committee held on 27.05.2021 Commercial Sub-Committee had accorded the recommendations of the special meeting on post-facto adjustment/accounting of drawals of nuclear stations held on 28.04.2021 and requested to implement the same.


b) SRLDC had informed that they have taken up with the vendor M/s PwC for implementation of the negative DC punching provision in the scheduling software and they were facing few issues with M/s PwC for the implementation. Also new WBES implementation was also in the offing. They were trying to implement the provision as recommended by Commercial Sub-Committee at the earliest and assured to implement at the earliest.

B. Settlement of deviation of NPCIL Stations during drawal period:

i) In 49th Meeting of Commercial Sub-Committee held on 03.09.2021, SRPC Secretariat had proposed the following methodology:

[Basis: As per the CERC (Deviation Settlement Mechanism and related matters) Regulations, amended to date, the charges for the deviation for all the generating stations (whose tariff is determined by the Commission and others), irrespective of the fuel source, when actual injection is higher or lower than the scheduled generation, shall not exceed the Cap Rate of 303.04 Paise/kWh.]

1. The deviation of NPCIL Station/Unit (Actual injection is higher or lower than the scheduled generation & drawal of power during shutdown) may be settled as per Proviso (ii) to clause (1) of Regulation 5 of the DSM Regulations. i.e, not exceeding the Cap Rate of 303.04 Paise/kWh.

2. The deviations by Nuclear Station/Unit shall be settled by the beneficiaries of the NPCIL Station/Unit with the DSM pool.

3. Post facto adjustment (block-wise) in the weekly DSM account shall be carried out as follows:

a) The deviation (over injection/under injection/drawal) by NPCIL Station/Unit shall be apportioned among the beneficiaries in the allocation ratio. This energy would be settled by the beneficiaries to the DSM pool (on post facto adjustment).

b) The charges for the apportioned energy (deviation by NPCIL station) shall not exceed Cap Rate of 303.04 Paise/kWh.

Note: After the commencement of negative DC punching by NPCIL stations, the deviation shall be computed on actual drawal versus negative schedule of the station (i.e. the under drawal/over drawal from the schedule (-ve) only be settled at the charges for deviation) since the drawal schedule of the beneficiaries would be finalized based on the negative DC of the NPCIL stations.)

4. NPCIL Station/Unit shall settle the drawal during shutdown period with the beneficiaries at the monthly billed Tariff of the respective station. This would be in the way of adjustment in the monthly bills based on the REA (i.e. billing based on the net energy to the beneficiaries when the Station/Unit starts generation and the energy drawn by the station/unit needed to be settled in the first month billing itself after commencement of generation).

ii) Commercial Sub-Committee recommended the proposal and decided to put up in the upcoming TCC/SRPC meetings for approval. This would be implemented subsequent to the


approval of TCC/SRPC. Till that time existing DSM postfacto accounting methodology would continue.

This may please be approved.

V. Items for Update

i. Operation

Ou.1. Proposals agreed in the 3rd Meeting of Southern Regional Power Committee (Transmission Planning).

1.1 The 3rd meeting of Southern Regional Power Committee (Transmission Planning) [SRPC (TP)] was held on 24.08.2021 through VC. The Minutes of the meeting available at CEA website: https://cea.nic.inunder Committees>Regional Power Committee (Transmission Planning) (RPCTPs) > Southern Region

1.2 The following schemes/proposals agreed in the meeting needed to be taken up for implementation:

1) Scheme to bypass NGR to use Switchable Line Reactor as Bus Reactor:

a) SRLDC in its operational feedback has suggested to implement NGR bypass arrangement for switchable line reactors to use them as bus reactor, in case of outage of line. Implementation of Vemagiri – Chilkaluripeta 765kV D/c line along with 240 MVAR switchable line reactor at both ends of each circuit and Chilkaluripeta – Cuddapah 765kV D/c line along with 240 MVAR switchable line reactors at both ends of each circuit as part of “Strengthening of transmission system beyond Vemagiri” was agreed as in the 37th meeting of the SCPSPSR held on 31.07.2014.

b) SRPC (TP) has agreed to implement NGR bypass arrangement to use switchable line reactors (240 MVAR each) as bus reactors installed on each circuit of Vemagiri – Chilkaluripeta 765 kV D/c line and Chilkaluripeta – Cuddapah 765 kV D/c line at Chilkaluripeta 765 kV S/s.

c) This has been discussed in the 184th meeting of OCC held on 10.11.2021 wherein PGCIL informed that formal letter from CTUIL is required for implementation. CTUIL has informed that they would take up with PGCIL.

2) Assessment of online Dynamic Line Rating:

a) As per the directions of CERC regarding implementation of assessment of Dynamic Line Loadings in real time / day ahead for optimal utilization of transmission lines, the matter was discussed in 37th SRPC and 167th OCC meetings held on 01.02.2020 and 13.03.2020 respectively. In the OCC meeting it was decided that SRPC may take up the matter with POSOCO/CTU to have a pilot project on any critical line in Southern Region. Member Secretary, SRPC vide letter dated 16.03.2020 had requested to have a pilot project on any critical line in Southern Region.


b) SRPC (TP)has agreed to consider the following lines for assessment of Dynamic Line Loadings as a pilot project and SRPC was requested to take further action on the issue:

i. Tuticorin PS- Madurai 400 kV D/c (quad) line (line length 95 km)

ii. Kalpakka – Simhadri 400 kV D/c line (line length 4 km)

c) This has been discussed in the 184th meeting of OCC held on 10.11.2021 wherein PGCIL was requested to implement the scheme

3) Requirement of 765 kV spare (1-Ph) Reactors units:

a) One spare unit (1-Ph) of 80 MVAR reactor has not been considered for 765 kV Warangal New and Chilkaluripeta TBCB substations. Therefore, it is proposed to provide one spare unit (1-Ph) of 80 MVAR reactor at each 765 kV Warangal New and Chilkaluripeta TBCB substations along with necessary arrangement to take spare reactor units into service as per requirement.

b) SRPC (TP) has agreed to the proposal of providing one spare unit (1-Ph) of 80 MVAR reactor at each 765 kV Warangal New and Chilkaluripeta TBCB substations along with necessary arrangement to take spare reactor units into service as per requirement.

c) This has been discussed in the 184th meeting of OCC held on 10.11.2021 wherein PGCIL informed that formal letter from CTUIL is required for implementation. CTUIL has informed that they would take up with PGCIL.

4) Conversion of fixed line reactor into switchable line reactor / bus reactor:

a) Veltoor – Raichur 400 kV S/c line (about 74 km) is installed with 50 MVAR fixed line reactor at Raichur TPS end under the ownership of Raichur TPS. SRLDC has reported resonance phenomena on above mentioned line during tripping. In view of above, it is proposed to convert fixed line reactor installed at Raichur TPS for Veltoor – Raichur 400 kV S/c into switchable line reactor with inter trip scheme. If due to space constraint or any other issue it is not possible to convert fixed line reactor as switchable line reactor, then same could be converted into bus reactor at Raichur TPS.

b) SRPC (TP) has agreed that KPTCL will take up the matter with KPCL for converting fixed line reactor installed at Raichur TPS end of Veltoor – Raichur 400 kV S/c line into switchable line reactor with inter –trip scheme.

c) This has been discussed in the 184th meeting of OCC held on 10.11.2021 wherein KPCL was requested to implement the scheme.

5) Use of switchable line reactors as bus reactors at Kurnool Sub-Station:

a) SRPC (TP) has agreed to the proposal of using 2x240 MVAR switchable line reactors at Kurnool 765kV S/s as bus reactor till commissioning of Hyderabad– Kurnool 765kV D/c line.


b) This has been discussed in the 184th meeting of OCC held on 10.11.2021 wherein PGCIL informed that formal letter from CTUIL is required for implementation. CTUIL has informed that they would take up with PGCIL.

Ou.2. Automatic Under Frequency Load Shedding (AUFLS) Scheme - Review of Settings

2.1. As per the decision in the 2nd meeting of NPC held on 16th July 2013, the following AUFLS scheme at four (4) stages of frequency viz. 49.2 Hz, 49.0 Hz, 48.8 Hz & 48.6 Hz had been implemented in all the regions.

2.2. In the 8th Meeting of NPC, it was decided that the frequency settings of AUFLS scheme (with 4 stages ) may be raised by 0.2 Hz viz. 49.4, 49.2, 49.0 & 48.8 Hz and quantum of load shedding may be worked out considering the requirement to increase the frequency to 50 Hz.

2.3. In the 9th meeting of NPC, it was decided that a Sub-Committee may be formed under the chairmanship of Member Secretary, WRPC, with representatives from POSOCO and all the RPCs to study the AUFLS Scheme and submit its report to the NPC. Subsequently, NPC Secretariat vide letter dated 19.01.2021 has formed the Sub-Committee under the Chairmanship of Member Secretary, WRPC with representatives from POSOCO and all the RPCs to study the AUFLS Scheme.

2.4. In the 10th meeting of National Power Committee (NPC) held on 09th April 2021, it was decided that the AUFLS scheme (with 4 stages ) viz. 49.4, 49.2, 49.0 & 48.8 Hz with existing quantum of load shedding shall be implemented in all the Regions. The quantum of load shedding would be reviewed based on the recommendation of the Sub- Committee to study the AUFLS scheme.

2.5. In the 181st meeting of OCC held on 10.08.2021, it was agreed for Implementation of revised frequency setting of AUFLS scheme (with 4 stages) viz. 49.4, 49.2, 49.0 & 48.8 Hz with existing quantum of load shedding.

2.6. TSTRANSCO, KSEBL & TANTRANSCO have implemented the revised settings.

2.7. In the 184th meeting of OCC (10.11.2021), the forum approved the revised quantum proposed by APTRANSCO and requested APTRANSCO to expedite the implementation of revised settings. In that meeting, KPTCL and Puducherry have informed that the revised setting had been implemented and the report would be submitted shortly.

Ou.3. Progress of bus/line reactors to be commissioned in SR

3.1 Status of implementation of Bus / Line Reactors approved in the Standing Committee / SRPC pending for commissioning by the SR constituents is at Annexure-Ou.3.1.

States to update the status of implementation of Bus / Line Reactors approved in the Standing Committee.


3.2 Re-installation of failed Shunt Reactor II (400 kV 80 MVAR) at KKNPP:

• The shunt reactor was commissioned on 05.10.2012. The same was failed and Out of Service from 14.12.2016.

In the 183rd meeting, KKNPP informed that contract for repair work for bus reactor 00ACR50–R phase will be tentatively awarded in October middle -2021 and further almost 5-6 months are required for repairing &restoration of shunt reactor 00ACR50.

Ou.4. Reactive Power Planning – STU/DISCOMs

Status of Capacitor installation in Transco/Discoms is at Annexure-Ou.4.

States to update the status of capacitor installation in Transco / Discoms to SRPC Secretariat.

Ou.5. Implementation of SAMAST by State Utilities

The following had been noted in the previous meetings of OCC (latest update in the 182nd OCC on 09.09.2021):

a) APTRANSCO had informed that grant sanctioned from PSDF. Both software and hardware part under tendering state.

b) KPTCL had informed that SAMAST project has been approved and Rs.9.00Crores has been sanctioned from PSDF. Work Award was issued during August 2021and the works under progress. One year from DWA is the target date of completion.

c) KSEBL had informed that they had submitted DPR (Rs.53 crores) to NLDC for funding from PSDF. Tender for meters floated and tender for AMR and software part would be floating shortly. Grant of Rs.15.80crores has been sanctioned from PSDF.

d) TANTRANSCO had informed that out of 13 modules, 6 modules viz. Scheduling, DSM, Metering, Grid Connectivity, Entity User Management and RPO were completed/in progress. For remaining 7 modules development work was completed and testing is in progress. One more module is coming under operation from September 2021.

e) TSTRANSCO had informed that SAMAST DPR (around Rs.50 Crores) was submitted to the Techno Economic Committee of PSDF long back. The DPR was revised multiple times. The amount was reduced to Rs. 45 Crores.. The revised DPR for SAMAST would be submitted to NLDC.

All the states are requested to furnish the status update on the Implementation of SAMAST.

Ou.6. Pump Storage Plants (PSP)

a) The status of upcoming Pump Storage Plants in SR is at Annexure-Ou.6.


b) APGENCO had informed that DPR had been submitted by WAPCOS. Permission is awaited from CEA/CWC/MoEF for pumped storage scheme at Upper Sileru (9x150 MW). Expected to be commissioned by June 2021.

States are requested to update the status of implementation of PSP.

Ou.7. New Projects of NTPC, NLCIL, NPCIL, BHAVINI & UMPP

Schedule of synchronizing/commissioning of the new projects of NTPC, NLCIL, NPCIL, BHAVINI& UMPP is at given below:

A. NTPC- Telangana STPP Phase-I(2 x 800 MW)

The following had been noted in the earlier meetings:

i) MoP vide letter dated 05.02.2019 has allocated 85 % to Telangana and balance 15% will remain earmarked as “unallocated power” and is placed at the disposal of Central Government for meeting urgent/continent requirement of States/UTs from time to time.

ii) TSRANSCO had stated that as per AP Reorganization Act, this project is fully intended for Telangana state. It is learnt that it is treated as ISGS project and 15% is left as unallocated and could be allocated to other states. TSTRANSCO had informed that at Government Level the issue has been taken up with MoP.

iii) CoD: Unit-1 (October 2020) Unit-2 (February 2021)

B NTPC- Pudimadaka (AP)(4 x 1000 MW)

The following had been noted in the earlier meetings:

i) 52 Months from Zero Date. Zero date yet to be finalized.AP had requested NTPC to firm up the zero date at the earliest.

ii) NTPC had informed that MoP has allocated 50% to home state (AP) and balance allocation has to be made.

iii) NTPC informed that as per Tariff Regulations 2019-2024, fresh consent shall be taken from the beneficiaries. This plant was planned through imported coal. They would go ahead only with fresh consent from beneficiaries.

C NLCIL-TPS-II 2ndExpn(2 x 660 MW) 2nd SRPC (TP) U1: 2025-26 Connectivity required 2024-25

D NPCIL- KKNPP Unit 3 & 4 (2x1000 MW) 2nd SRPC (TP)- LTA is sought by March 2023 37th TCC : U3- September 2024 U4- March 2025 Connectivity by 2024

E NPCIL- Kaiga GS Units 5 & 6 (2x700 MW)

37th SRPC: i. NPCIL had informed that in the joint study meeting of SR held on 21st& 22nd November 2019,

re-conductoring of existing evacuation lines and upgradation of KGS switchyard had been discussed. During reconductoring, KGS would be operated with lower reliability. A note in this regard was under approval.

ii. CTU had stated that KGS may arrange the forest & environmental clearance for reconductoring the existing lines. CTU also informed that they had received LTA application from NPCIL and further action would be carried out after the grant of LTA. It was technically


agreed for replacement of conductor of 230 kV lines of KPTCL.

iii. NPCIL had stated that they would obtain necessary clearances from Forest Department for carrying out the work of reconductoring of the transmission line for enabling evacuation of power from Kaiga APP (2x700 MWe), as the establishment of Kaiga U 5,6 (2x700 MW) would not be possible without re-conductoring of the transmission line.

F BHAVANI-Kalpakkam (PFBR) (1x500MW) By end of 2020

G UMPP-Krishnapatnam(6 x 660=3960 MW) APTRANSCO had informed that a letter dated 20.10.2019 was addressed by APSPDCL to TSSPDCL requesting to file petition on behalf of all procures as TSSPDCL is the lead procurer. Further M/s RPL/CAPL had filed WP(C) No.9062 of 2019 before Honorable High Court of New Delhi requesting of buy back of the project by PFC/Procurers or to allow M/s RPL to sell/utilize the land acquired for the project. In this regard a counter was filed to the above Petition on 14.11.2019. The matter was listed for hearing on 09.07.2020 but, no hearing was happened. Further, the case is not listed so far before the Honorable High Court of New Delhi.

9 UMMPP-Cheyyur(4000MW) i) Request for Qualification (RfQ) and Request for Proposal (RfP) issued in 2013 were

withdrawn. A fresh bid would be issued after finalization of SBDs. However, recently MoP is examining the possibility of setting up Cheyyur UMPP on domestic coal instead of imported coal. For setting up of this UMPP on domestic coal, additional land of about 767 acres for Ash Dyke area would be required. Power Finance Corporation has taken up the matter of identification of additional land for Cheyyur UMPP with the Govt. of Tamil Nadu. Ministry of Coal has been requested to identify the suitable coal blocks

ii) TANGEDCO had informed that stakeholder discussions were held, and most of the utilities are not interested and have opted out. They were taking up with MoP for closure or downsizing of the project.

Ou.8. Upcoming Transmission System

8.1 Upcoming inter-regional transmission schemes

a) WR-SR 6000 MW HVDC Bipole Link [Raigarh (Chhatisgarh)-Pugalur (TN)-Trissur (KER)]

Status of Transmission System as on 05.11.2021:

Sl. N

o.

Sche

me

Element OLT

(Open Line test)

First Time Power

Flow date

DOCO Remarks

1

1

RP800 Pole-1 11.12.2019 16.05.2020 06.09.2020 2 RP800 Pole-2 30.12.2019 26.05.2020 09.03.2021 3 RP800 Pole-3 05.12.2020 24.06.2021 13.07.2021 4 RP800 Pole-4 29.01.2021 02.03.2021 25.10.2021

5

2

400kV Pugalur HVDC - Arasur D/C 19.08.2020

(FTC) 06.09.2020

6 400kV Pugalur HVDC - Pugalur D/C 14.05.2020

(FTC) 06.09.2020

7 400kV Pugalur HVDC - Udumalpet D/C (Edayarpalayam SS Bypassed)

06.07.2021

(FTC) 13.07.2021

8 400kVPugalur HVDC - Thiruvallem D/C - 25.10.2021


9

3

PK2000 Pole-1 12.11.2020 15.12.2020 08.06.2021 OLT with line 03.12.2020

10 PK2000 Pole-2 27.10.2020 05.12.2020 09.03.2021 OLT with line 20.11.2020

.

b) Additional inter-Regional AC link for import to Southern Region, i.e., Warora - Warangal - Hyderabad- Kurnool 765 kV link

[TBCB, PFCCL-BPC, Transmission Licensee: Warora_Kurnool Transmission Limited (WKTL)]

i) The following had been noted in the earlier meetings:

M/s WKTL had stopped the execution of Warora- Warangal 765 kV line work based on the objections of Western Coalfields Limited (WCL) and Singareni Collieries Company Limited(SCCL) due to crossing of the Warora –Warangal line in the proposed coal fields of these coal companies.

Chairperson, SRPC had agreed to take up the concern of SR constituents with MoP.

ii) Chairperson, SRPC vide letter dated 10.02.2020 had taken up the concern of SR States with Secretary, MoP.

iii) Hyderabad-Kurnool 765 kV DC line being executed by WKTL was stalled. The Scheduled COD of the line is 05.11.2019. However, PGCIL executing the line bays at Kurnool SS completed the bay work and proposed to commission the bay on 11.03.2019 and convert the line reactor into bus reactor which was concurred in 36th SRPC meeting. However, during the hearing of the Petition No.248/TT/2019, TANGEDCO raised objections for including the capital cost of assets in the PoC pool as the intended purpose of the line reactor and bays was to provide connectivity to 765 kV Hyderabad-Kurnool line which was delayed by WKTL. Since the Regulation mandates the entity attributing the delay to bear the transmission charges liability, WKTL is liable to pay the transmission charges at least from the scheduled COD till they commission the transmission line.

iv) Updates from CEA Report for August 2021:

Ministry of Power (MoP) vide letter No. 7/1/2017‐Trans dated 16.04.2020 has conveyed the following:

1. MoP, GoI has decided that M/s WKTL, the developer of Warora-Warangal 765 kV

D/C Transmission Line is required to complete the balance works in above line as per the original approved route in the coal bearing area of WCL involving 16 towers without any further delay and also to comply all other decisions of MoP conveyed as per above letter dated 16.04.2020. Further, WKTL is required to complete all the elements in the above Scheme within the framework of the contractual obligations. It is also requested that the latest status and implementation schedule of all the elements of above line may be conveyed to CEA at the earliest.


2. Lead Long Term Transmission Customer(LTTC), i.e., TANGENDCO Ltd, is requested to take necessary action as per TSA to ensure that there is no further delay in completion of the above project.

M/s WKTL is also advised that in case of any constraints in completion of the above project as per established procedure, the developer may approach CERC for redressal of the issues if any, as MoP/CEA only facilitates the project implementation in a time bound manner. The Project was stalled due to force majeure issues including non resolution of issues pertaining to coal bearing areas associated with Western Coal Fields (WCL) and Singareni Coll. Co. Ltd. (SCCL)

While WKTL has filed detailed petition (dated 5th March 2020) with Central Electricity Regulatory Commission for extension of Scheduled Commercial Operations Date along with consequential reliefs, Project implementation is expected to be further worsened pursuant to lockdown imposed by the Central Government of India wherein on all movements have been restricted from 24th March to 14th April owing to Corona Outbreak /Pandemic (COVID-19). and impact of the same continued till Jun-2020. Due to Continuation of the Force majeure conditions and non-completion of the Work, CERC issued the order dated 07-02-2021, wherein CERC has granted liberty to the WKTL to approach the Commission to seek the appropriate relief for force majeure events, after completion of the Project. Also CERC ordered that no precipitative actions to be taken against the WKTL as the subsistence of TSA in the interregnum is vital to the completion/ implementation of the Project. Meanwhile, instructed WKTL shall make sincere endeavors to complete the Project.

The lenders of WKTL have filed Petition (71 /MP/2020) with Central Electricity Regulatory Commission seeking approval under Section 17(3), &(4) and Section 79(1)(c) of the Electricity Act, 2003 read with Regulation 12 of the Central Electricity Regulatory Commission (Procedure, Terms and Conditions for grant of Transmission License and other related matters) Regulations, 2009 and Article 15.3 of the Transmission Service Agreement dated 06.01.2016 for the approval of the Hon’ble Commission to transfer the shares and management control of WKTL in favour Adani Transmission Ltd. as Adani Transmission Ltd has been declared successful bidder for acquisition of WKTL, pursuant to public auction conducted by consortium lenders through an independent consultant.

CERC has issued order on 27th January, 2021 and granted approval for transfer of 100% shareholding/ any other securities held by Essel Infra or its affiliates (including that which is held under pledge by the Lenders) in WKTL in favour of ATL (Adani Transmission Limited) by execution of Share Purchase Agreement. Based on the order issued by the commission SPA carried out with Essel Infra on 26-03-2021.

c) Updated status of upcoming Inter Regional Transmission scheme is furnished at Annexure-Ou.6.1.c.).


8.2 Status of important associated transmission evacuation systems

Transmission Elements

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

APTRANSCO ; 400 kV TM D/C Kamavarapukota – Vemagiri; 186.8 ckm AP: 183 OCC : Expected commissioning by 31.12.2021 (out of 268 Nos of tower locations, 137 nos locations are in paddy fields which are having 3 Crop seasons/year and average working season in a year is 45 days. 13 Nos locations are having severe ROW issues. Stringing 100.508/186.8 km)

B Transmission system of KPTCL for evacuation of power from Yermarus TPS (2 x 800 MW)

KPTCL: Gulbarga 400/220 kV substation- 2 x 500 MVA,

KPTCL Report (September 2021): LOI issued on 10.06.2020 for Substation to M/s Kalapaturu Power Transmissio Ltd, Gandhi Nagar. Letter addressed to the firm to start the work on 09.07.2020.Land handed over on 08.07.2020. Block level & geo-tech Survey Completed. Activity Chart approved on 17.10.2020. Land leveling, control room & 400 kV & 220 kV side tower excavation work, control room building, Transformer excavation works etc under progress. Original Schedule: December 2021: Revised Target: February 2022.

Progress as on 30.09.2021: Approach Road, 400 kV & 220 kV side tower foundation work, control room building, Transformer excavation works etc under progress.

Yeramarus TPS - Gulbarga 400 kV D/C line (QM):

KPTCL Report (September 202) : CKM: 232.536: Toatla No of locations: 331, Towers erected:216. Stringing completed: 32.248, Original Schedule: December 2021: Revised Target: February 2022. As per estimate and award the tower locations were 317 Nos., but now at the time of execution and check survet the locations have been increased to 331 Nos. Progress as on 30.09.2021: 400 kV Line : No of Loc : 331 No's (as per Check Survey) Excavation : 271/331 No's , Stub Conc : 264/331 No's, Tower Erection - 234/331 No's Stringing : 25.8/117.055 Km's

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

38th SRPC: Land identified acquisition of land under progress. Gazette notification issued on 17.09.2020. Progress as on 30.09.2021: Land acquisition under progress.

LILO of Nelamangala – Talaguppa 400 kV D/C at CN Halli, 36thSRPC: Land identified acquisition of land under progress.

Termination of 400 kV D/C of Hassan from Nelamangala – Talaguppa at CN Halli 400 kV, Bellary PS - C.N.Hally 400 kV D/C line QM : 36thSRPC: (a) line commissioned (b)400 kV line from Rampura limit to Jagalur : Line work completed.(c) 400 kV line from Jagalur to Chikkanayakanahalli : To be tendered.

400 kV BTPS-Guttur D/C (QM), 36thSRPC: Estimate under preparation. 37th TCC: Estimate submitted to Corporate office on 11.08.2020 for preparation of DPR.


De-link 400 kV S/C RTPS-BTPS-JSW-Guttur with JSW Bus The matter was discussed in a meeting held on 22.11.2019 chaired by Chairperson/Member (PS), CEA, with representatives from KPTCL, SRLDC, JSW, CEA and CTU. Operational feedback (POSOCO) July 2020: 400 kV Jagalur PS Chikkanayakanahalli – Kadakola D/C line needs to be expedited. 37th TCC: Estimate under preparation.

C 400 kV Mangalore (UPCL) – Kasargode-Kozhikode: NCT in its 1st meeting had approved the scheme through TBCB.

EPC Partner has been taken on board, Detail Survey is in process, Foundation work will be started by Sept’20, after receipt of Sec-164 approval andGazette Notification for Sec-164 has been published. RECTPCL is the BPC. Being developed by M/s Sterlite Grid Limited. Udupi Kasargode Transmission Limited (UKTL) Petition No 336/AT/2019 (for adoption of transmission charges) was heard on 19.11.2019 and the Commission had reserved the Order. Hon’ble CERC had issued Order dated 27.12.2019 on Petition No 335/TL/2019 on ‘Grant of transmission license to UdupiKasargode Transmission Limited (UKTL)’. Status as per CEA Report August 2021: The Ministry of Power, GOI has granted extension of 5 months (for First wave of Covid-19) vide order nos 3/1/2020-Trans dated 27th July, 2020 and further 3 months extension (for Second wave of Covid-19) on 12 June, 2021 from Scheduled Commercial Operation Date (SCOD) for inter-state transmission projects i.e. total extension of 8 months from SCOD.

D 400 kV Hiriyur – Mysore line; 412 CkMalong with 2 x 80 MVAR Switchable line reactors at 400/220 kV Mysore S/S; PGCIL Declared on COD wef 01.05.2020

E 400 kV Pavagada – Devanahalli D/C line; (139.30 D/C and 13.20 M/C); PGCIL Progress affected due to limited permission with regard to interstate movement of labours/ Quarantine compliance in view of COVID-19 and ROW issue especially in Bangalore area Long duration outage requirement on 400 kV Nelamangala –Hoody & Yelahanka –Hoody line A special meeting was held on 27.02.2020 to discuss the issues w.r.t. shutdown (MoM available on SRPC website) The following had been noted in the OCC Meetings:

The lines had been taken out from 05.03.2020.

SR-II had informed that they are regularly updating to KPTCL, SRLDC/SRPC about the progress. The manpower was severely affected due to COVID-19 and they were planning to restore the lines by 31.08.2020.

KAR SLDC had expressed serious concern over the delay and suggested that the lines should be restored by 30.06.2020 as communicated in MD KPTCL letter.

A meeting was convened by CEA on 17.09.2020 to discuss the proposal of KPTCL regarding establishment of 3x500 MVA, 400/220 kV Devanahalli sub-station wherein in principle approval may be agreed for the following: a) LILO of 400 kV Yelahanka (Singanayakanhalli) - Hoody and LILO of 400 kV

Nelamanagala- Hoody line at 400/220 kV Devanahalli Sub-Station


b) 3 x 500 MVA, 400/220 kV transformers

c) 1 x 125 MVAR bus reactor

KPTCL would initially charge the 400/220 kV Devanahalli substation from Hoody end with 2x500 MVA transformers at 400/220 kV Devanahalli substation. SRLDC was also requested to give the charging clearance to KPTCL for the above works. It was also decided that the matter would be put up in the forthcoming SRPC(TP) meeting for ratification.

37th TCC:400 kV Pavagada – Devanahalli D/C lineis scheduled for charging by December 2020/January 2021.

F 2x500 MVA SS at Devanahalli Hardware Park - KPTCL SS commissioned in September 2020 with 1x125 MVAR reactor 37th TCC: Substation with 400kV line from Hoody commissioned on 24.09.2020 with 1x125 MVAR reactor. 220kV BIAL Begur to Devanahalli Hardware Park 2nd circuit commissioned on 06.10.2020.

Progress as on 30.09.2021: 2X500MVA S/s and 125Mvar reactor commissioned on 24.09.2020. TB at BIAL: Commissioned on 20.10.2020. TB at KIADB hardware park: Commissioned on 28.10.2020 ; TB at Hosakote: Commissioned on 09.02.2021 400kV Line--1 and 2 commissioned from 400kV Hoody end on 23.09.2020. 400kV Nelamangala Line commissioned on 13.11.2020 and 400kV Singanayakanahalli Line commissioned on 17.11.2020. 220kV MC line from proposed 400/220 kV S/s at Devanahalli Hardware park to 220/66kV Devanahalli HW park S/s charged on 31.12.2020. Construction of 220kV MC transmission line with AAAC Moose conductor from C point at proposed 400/220 kV S/s at Devanahalli Hardware park to 220/66kv Doddaballapura NRS S/s (2 Circuits )(25.10km) • Modification request from M/s BMRCL for tower heightening at 4 Locations near National Highway crossing – Work under progress • Similarly, modification request from Railways for tower heightening at 2 Locations near ITC Factory – Work under progress • 83/94 Tower stub foundation completed. 62/94 Towers erection completed, 14.6 /25.10 km stringing completed. balance work to be taken up. Approval is received from corporate office on 14.09.2021 to approach the DC, Bengaluru urban to fix the compensation for additional corridor for the special designed horizontal towers. Stringing of 220kV - 2nd circuit from BIAL to Hosakote commissioned on 22.12.2020

G LILO of Somanahalli - Kolar S/C line to Mylasandra (New Electronic City) Check survey approved on 23.07.19. The design documents of 400 kV towers had been approved. Foundation drawings submitted on to CEE, P&C by agency.

H 3x500 MVA SS at Mylasandra - KPTCL

400kV side : GIS Module equipment testing, HV testing completed and C&R Panel testing completed. 220kV Side: 220kV module equipments and HV testing completed and C&R Panel testing under progress. TBs at Yaraandanahalli: minor works like dismantling of CTs and PTs


from old Hosur bay to be taken up.

Progress as on 30.09.2021: 3*500MVA Transformer commissioned on: 31.03.2021. All TBs at Yerrandanahalli

commissioned.

400kV Line: Commissioned on 29.03.2021. Line documents handed over to M/s PGCIL on 09.06.2021.

220kV: Mylasandra-Yerrandanahalli: All works completed and line charged.

Mylasandra-HSR LILO line: Line charged on 14.07.2021.

UG Cable Portion: 4/4 sections of cable laying completed. • One number (01) of 220kV MC Cable terminating tower foundation and erection work completed. Cable supporting structures fabrication and fixing is under progress.

I 400 kV Madakkathara (Trichur) – Areekode (Kozhikode) - Kasaragode KSEBL had informed that line consist two stretches, 400 kV Madakkathara – Malaparamba and Malaparamba – Areakode. The works are to be carried out in the existing 220 kV circuits. Operational Feedback (POSOCO) July 2020: For S3 transfer capability/reliability

Status as on 01.11.2021: 400kV Madakkathara - Areekode line commissioned on 18.01.2021.

J Telangana STPP - I (2 x 800 MW) Power Evacuation Scheme

TS Update.(as on 01.11.2021): All the works are completed and the Substation & Bays are commissioned and lines are test charged from Narsapur SS and Ramadugu SS end as detailed below:

Sl.No

Name of the line/SS/Bays Date of test charging

I. 400kV QMDC Line a 400kV QMDC line from NTPC-Narsapur Line

(Circuit-I&II) -177.202kM 25.08.2021

c 400kV QMDC line from NTPC-Ramadugu Line (Circuit-I&II ) – 51.787kM

24.08.2021

II 400kV Ramadugu SS 10.02.2020 III 2 No. Bays at 400kV Narsapur SS 30.05.2019

K 400/220 kV Kadakola S/s (KPTCL)

Operational feedback (POSOCO): To address N-1 of 2x315 + 1x500 MVA ICTs at Mysore. Progress as on 30.09.2021: Revised estimate duly attending the observation sent to CEE P&C from CEE TZM submitted on 4.8.2021, DPR under Preparation.

L 400/200 kV Arasapadavu S/s (KPTCL)

Operational feedback (POSOCO): To address N-1 of 2x315 MVA ICTs at UPCL. Progress as on 30.09.2021: Land acquisition under progress. Estimate to be prepared.

8.3 Associated Transmission Evacuation Schemes in Tamil Nadu

Status of the following stations, evacuation schemes finalized in the 37th SCPSPSR, which were modified in the subsequent Standing Committee Meetings, is given below:


Generating Station Likely COD Evacuation Status (TN Update)

Ennore TPS Expansion – 1x660MW 36thTCC/37th SRPC: 2022-2023

Ennore SEZ (NCTPS Stage-IV) –2x660MW

36thTCC/37th SRPC: 2020-2021

Update from TN: Project Synchronisation is expected During 2022-2023

NCTPS Stage III – 1 x 800 MW * 36thTCC/37th SRPC: 2020-2021

Update from TN: Project Synchronisation is expected During 2021-20222

*1st SRSCT: Contingency measure: i) LILO of Manali – Alamathy 400 kV line at North Chennai 765/400 kV Pooling Station.

ii) This LILO arrangement would be made by utilizing a portion of 765 kV North Chennai PS – Ariyalur D/C line

Ennore TPS Replacement -1 x 660 MW

36thTCC/37th SRPC: 2022-2023

Work under progress

SEPC (1x525) 36thTCC/37th SRPC: 2020-2021

41st SCPSPSR: Require start up power for its Auxiliaries by April 2018.

SEPC-Thennampatty 400/230/110 kV

37th TCC: Energized on 09.10.2020

SEPC- Ottapidaram 400kV (Regular evacuation)

765/400 kV, 2 x 1500 MVA Ariyalur SS

Work under progress. Probable date of commissioning: 31.12. 2021

765/400 kV, 3x 1500 MVA North Chennai PS (GIS)

Work under progress. Probable date of commissioning: December 2021

765/400 kV, 2 x 1500 MVA Coimbatore SS

Land registration is nearing completion. Survey work awarded to it's associated 765 KV line and it's 400 KV line work. Estimate is under preparation for floating Tender.

765 kV Ariyalur – Thiruvalam (PG) Works under progress. Will be energized on commissioning of Ariyalur 765KV SS. Probable date of commissioning: 31.12.2021

765 kV North Chennai PS - Ariyalur Work under progress. Probable date of commissioning: 31.12.2021

765 kV NCTPS III- North Chennai PS

Work under progress. Probable date of commissioning: 31.12.2021

400 kV Ennore SEZ-North Chennai PS

Work under progress. Probable date of commissioning: 31.03..2022

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

36thTCC/37th SRPC 2020-2021



Ou.9. Status of Implementation of downstream network by State utilities associated with ISTS substations of PGCIL

The following downstream network is to be expedited by the State entities:

Sl. No

Name of Substation

MVA Capacity

220kV Bays

Expected Schedule of Substation

Remarks

1 Tumkur (Vasantnarsapur)

2 x 500 6 Commissioned Construction of downstream T/L for 2 Nos 220 kV bays to be expedited by KPTCL.

2nd SRPC (TP): 2 nos. of 220 kV lines from 400 kV Tumkur was being planned for future loads of KIADB

– March 2022 37th TCC: 220 kV Tumkur –KIADB Industrial D/C line by March 2022

2 Yelahanka 2 x 500 10 Commissioned Only 2 out of 10 (6 under ISTS) bays utilized

2nd SRPC (TP): Proposal for strengthening of Bengaluru transmission network to utilize the remaining

bays at Yelahanka is under planning. 3 Bidadi 2 x 500 6 Commissioned Construction of downstreamT/L

for 4 Nos. 220 kV bays to be expedited by KPTCL.

220 kV Magadi-Bidadi line:

Progress as on 30.09.2021: 87/127 locations foundation completed,80/127 tower erection completed. Stringing:10.04kms /32.189kms completed.

220 kV Bidadi-Kumbalgodu Cable: Progress as on 30.09.2021: 48/54 section cable laying completed, 40/52 Joints completed, 21.617/24.25kms completed.

4 Hiriyur 2 x 315 6 Commissioned Construction of T/L for 2 Nos. 220 kV bays to be expedited by KPTCL.

400 kV Hiriyur to 220 kV Hiriyur: Progress as on 30.09.2021: TB work completed and commissioned. No of foundation completed: 24/28. No of erection completed: 22/28. Stringing completed: 7.235/15.168 kms

220 kV Hiriyur to Chitradurga: Progress as on 30.09.2021: Terminall bay work completed and to tested and commissioned. NH Authority taking up the work & said work is under progress. No of foundation completed: 152/152. No of erection completed: 152/152 Stringing completed: 36.506/ 36.506 kms.

5 Hassan 2 x 315 6 Commissioned Construction of downstreamT/L for 2 Nos. 220 kV bays tobe expedited by KPTCL.


Ou.10. New Projects of State Sector & IPP

a) Status of new projects of State sector is furnished below:

Sl No

Name of project Located in

Capacity in MW

Commissioning Schedule /Remarks

1 Dr. NTTPS, Vijayawada

AP 1 x 800 AP Update (July 2021): Boiler light up: 28.12.2012 Turbine is kept under barring gear on 22.02.2021 COD expected by October 2021

2 Krishnapatnam Stage II (U3)

AP 1 x 800 AP Update (July 2021): Boiler light up completed on 31.12.2019 Turbine is kept under barring gear on 08.03.2021Stage I, II& III boiler steam blowing completed on 07.04.2021, 24.05.2021 and 05.06.2021. Normalisation activities are under progress. Expected COD: 800 MW. 183rd OCC: Delayed due to issues with

2nd SRPC (TP): LILO of B4 circuit of Shimoga – Bangalore 220kV at Hassan – Mar’20. Progress as on 30.09.2021: Total Towers: 34; Stub concrete: 34/34 nos. Tower erected: 32/34 nos. Stringing: 4.458/ 7.14kms

6 Kolar 2 x 500 6 Commissioned Construction of downstreamT/L for 2 Nos 220 kV bays tobe expedited by KPTCL.

220 kV Kolar- Gollahalli D/C line: Progress as on 30.09.2021: 220kV line was commissioned on 15.03.2021 66kV out of 4 lines 3 lines were commissioned, remaining work under progress.

7 Kozhikode 2 × 315 + 1 x 500

4 Commissioned Construction of downstreamT/L for 1 No 220 kV bay tobe expedited by KSEBL

2nd SRPC (TP): Award by March, 20. 36thSRPC: KSEBL informed that only 3 bays will be used and they were planning to use HTLS due to ROW issues. KSEBL Update (as on 01.11.2021): KSEBL is enhancing the capacity of existing 3 nos. of 220kV feeders from 400kV Kozikode (PGCIL) S/s to 220kV Areekode (KSEBL) S/s by changing from single moose conductor to double moose conductor. With the upgradation of existing 3 nos. of feeders,N-1 security will be achieved. Accordingly, KSEBL is not planning to construct the 4th 220kV feeder between the sub-station at present. The work of upgrading the existing 220kV feeders is in progress and is tentatively scheduled for commissioning by end of November 2021.


APDISCOMs and Generator w.r.t payment.

3 Polaki AP 4000 (5 x 800 MW)

36th TCC/37th SRPC: Kept in abeyance due to non-willingness by AP Discoms.

4 Edlapur KAR 1 x 800 The project dropped

5 North Chennai Stage III TN 1 x 800 TN Update: 2021-22

6 Ennore SEZ STPP (North Chennai Stage IV)

TN 2 x 660 TN Update: 2022-23

7 Ennore TPS Exp TN 1 x 660 37th TCC:2023-24

8 Ennore replacement TN 1 x 660 TN Update: New Project

9 Udangudi Stage I TN 2 x 660 TN Update: 2022-23

10 Udangudi Stage II TN 2 x 660 TN Update: New Project

11 Udangudi Stage III TN 2 x 660 TN Update: New Project

12 Uppur TPP (TBCB) TN 2 x 800 37th TCC:2023-24

13 Manuguru TPP (Bhadradri)

TS 4 x 270 TS Update: U1 COD: 05.06.2020 U2: COD : 07.12.2020 U3: COD : 26.03.2021 U4: COD: Expected in Nov: 2021

14 Kakatiya TPP Stage III TS 1 x 800 No proposal of KTPP Stage III

15 Damaracherla (Yadadri) TS 5x800 TS update: U1:Commisioning by October 2022 U2 to 5: Commissioning by June 2023

b) 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 Unit 3 →Full Load on 15.04.2018, Unit 4 → Full Load on 05.07.2018 Untied: 640 MW

2 East Coast Energy Thermal

AP 2 x 660

Uncertain

3 Thermal Powertech (TPCIL) Unit-III

AP 1 x 660

Under planning

4 Godhna TPP, Janjir – ChampaDist, Chhattisgarh

For KAR

2 x 800 Sariya /Durgapur-II/ Taraimar coal mines allotted


Ou.11. Roadmap to operationalize reserves in the country- AGC Implementation

11.1 In the 29th Meeting of SRPC it had been noted that Hon’ble CERC vide Order dated 13.10.2015 on Petition No. 11/SM/2015 in the matter of Roadmap to operationalize Reserves in the country had stated as follows:

(b) (ii) The Central Commission advises the State Commissions to issue orders for intra-state generators in line with this timeline as AGC is essential for reliable operation of India’s large inter-connected grid.

……………

(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.

11.2 In CERC Order 319/RC/2018 dated 28.08.2019- Hon’ble CERC the following was stated:

In the interest of reliable and safe grid operation, the Commission directs that all the ISG Stations whose tariff is determined or adopted by CERC shall be AGC-enabled and the ancillary services including secondary control through AGC be implemented …….

11.3 Status update is as below:

a) Central Sector implementation:

Entity Generator Status NTPC Simhadri STPS Stage- II (2 x

500 MW) AGC implemented (18.11.2018)

Ramagundam STPS Stage- II (4x500 MW)

Commissioned on 31.03.2021.

Simhadri STPS Stage- I (2 x 500)

Simgadri STPS Stage-I units are kept in service from evening 4 to 7 hours as advised by NLDC(since last one week). The observations will be sent to NLDC from Corporate office.

Ramagundam STPS Stage-I (3x200 MW)

AGC implementation works would be taken after the maintenance/ renovation works.

Talcher STPS ( 4 x 500) NTECL Vallur TPS (3 x 500 MW) AGC is in place from 14.06.2021.

NLCIL TPS II (7 x 210 MW) By month end

TPS I Expn( 2 x 210 MW) By month end. TPS II Expn ( 2 x 250 MW)

NNTPS (2 x 500 MW) NTPL NTPL (2 x 500 MW) NTPL informed that AGC at NTPL is in

operation from 14.06.2021. Performance is


observed to be satisfactory.

NP-Kunta

Solar in AP AGC :5 blocks of 50 MW i.e. 5 x 50 = 250 MW

During the visit to NP Kunta on 06.08.2021 it was told that material has come for implementation. SRLDC agreed that they will update the actual status from NLDC.

b) AGC at state Level- Pilot Project identification & Implementation:

State Generator Status Andhra Pradesh

Krishnapatnam (2 x 800 MW) APTRANSCO vide communication dated 05.08.2021 had informed that implementation of AGC at SDSTPS, Krishnapatnam is under examination and pending with AP & not pending in Hon’bleAPERC.After finalization at management level in coordination with generator M/s.APPDCL and AP Disoms, the proposal will be submitted to the Hon’ble APERC for approval to implement the AGC scheme at Krishnapatanam.

In addition to Krishnapatnam planning AGC at VTPS, RyTPP, Upper Sileru& Lower Sileru.

Karnataka Sharavathy Generating Station (1035 MW)

Implementation of AGC Pilot under USAID GTG Scheme completed. Available MW for AGC is 10 % of Live load up to maximum of 100MW (10% 0f 1035 MW). KPTCL informed that at Sharavathi testing is over. In coordination with KPCL the units would be put under AGC operation.

Varahi Under Ground Power House(4 x 115 MW)

Hardware & software deployment and configuration completed (Nov 2020)Go-live pilot completed (Jan 2021).Available MW for AGC is 20% of live load upto maximum of 80 MW as per the programme planned. KPTCL informed that at Varahi testing is over. In coordination with KPCL the units would be put under AGC operation.

Kerala Kuttiady Unit No. 5 (50MW) Operational


State Regulator has been approached for putting AGC on regular basis

Idukki Unit No.1 (130MW) AGC would be implemented once the Optical Fibre link from SLDC to Idukki PH is established

Tamil Nadu North Chennai TPS Stage-II ( one unit i.e. 2 x 600 MW) Software: Algorithm

developed and completed.

Hardware: Procurement under progress by intend. Technical suitability awaited and work would be completed within three months from the date of PO.

MTPS - II (1 x 600 MW) Enquiry (OI no. 35/21-22) floated for supply, erection and commissioning of software, hard ware and implementation of AGC in MTPS II. Tender- Techno Commercial bid- to be opened on 17.08.2021.

Telangana KTPS- VI (500 MW) Kothagudem E (132 MW) downward)

TSTRANCO had informed that the signal had been sent from Generator end found OKAY. Signal of -25 MW was sent from SLDC side and it had reached generator and operated as designed. Final tuning is under progress.

Ou.12. Emergency Restoration System (ERS)

Requirement of ERS had been outlined in MoP letter dated 05.12.2014. The status is being monitored at higher level. Status is given below:

Transmission Utility

Requirement as per MoP

Existing Status/Remarks as noted in 182nd OCC

APTRANSCO 3 2 APTRANSCO informed that *

* against the suggested quantity of 3 sets of ERS in the state by MoP, 2 sets of ERS infra structure consisting of 20 Nos towers were procured by AP and placed at three different locations, 3 nos in Srikakulam, 7 nos in Visakhapatanam and 10 Nos in Nellore coastal districts to meet the exigencies in case of natural calamities for restoration in the existing transmission network. No other ERS System is under procurement.

KPTCL 2 2

KSEBL 1 0 KSEBL had informed that #


# Because of ROW issues ERS may not be useful in Kerala which was the opinion arrived in the pre-bid meeting. KSEBL had informed that they have taken up the issue with Transmission wing and a communication from Transmission wing would be arranged to SRPC in this regard. In the 181st OCC Meeting they will take up and will arrange the communication. It was emphasized that the information needed to be put up to SRPC/TCC forums.

TANTRANSCO 2 0 ERS will be in place by January 2022

TSTRANSCO 1 0 Bids opened and finalization under progress

PED Nil Nil

PGCIL 4 4 SR-I & SR- II Two Nos. Each in place

VI. Items for Information (i) Operation

Oi.1 Reserve Shut Down (RSD) Issues

1.1 The following had been noted in earlier meetings:

a) SRPC vide letter dated 25.02.2020 had requested Hon’ble CERC to consider the procedure recommended by SRPC forum.

b) SRPC vide letter dated 04.06.2020 had requested POSOCO to consider whether the entitlement computation during RSD of unit was in line with CERC Order dated 04.02.2020 in petition No 114/MP/2018. POSOCO had replied vide letter dated 30.06.2020.

c) A special meeting was held on 19.08.2020 & 03.09.2020 (MoM available on SRPC website) wherein RSD procedure was finalized to be implemented in SR. Further a mock was planned for 2 months to create entitlements as per requisitions to address the compensation and various other issues raised by SR constituents.

1.2 Updates:

i. All the utilities had conveyed concurrence for implementation of new RSD procedure on trial basis for two months.

ii. In the 179th meeting of OCCTSTRANSCO had requested SRPC/SRLDC to take immediate action to implement the RDS procedure (trial run for two months) at the earliest or modify the Entitlement ON bar & OFF bar quantity to reduce part load compensation liability of TSDICOMs who is actually not a part in part load operation. All the states had agreed in principle for the procedure for implementation off bar.

iii. In the 180th meeting of OCC, SRLDC had presented the status of implementation. It was noted that a web based application was developed by SRLDC internal IT team. SRLDC demonstrated base case for new RSD procedure. SRLDC informed that by


14.07.2021 all the works w.r.t the implementation including testing would be over. From 15.07.2021 mock trial (without commercial implication) may be started (till 18.07.2021) to experience the impact by States. In consultation with SRPC, trial run for 2 months may be started from 19.07.2021. The data would be jointly validated jointly by SRLDC and SRPC before officially submitting to SRPC for commercial accounting.

iv. As agreed in the 180th meeting, a workshop was conducted on 13.07.2021 with participation from all the concerned entities wherein it was agreed for Mock trial for 10 days from 15.07.2021 to 24.07.2021.

v. The mock trial had been successfully completed on 24.07.2021.

vi. A Meeting was carried out on 27.07.2021 wherein the experience of mock trial run of the experience were shared by SRLDC/ State SLDCs/SRPC and the following had been agreed:

a) Trail Operation of New RSD Procedure will be implemented from 01.08.2021 for a period of two months i.e. till 30.09.2021.

b) All data would be validated by SRLDC/SRPC before using the same for commercial implications.

c) Comments and observations, if any, would be communicated to SRLDC/SRPC on a weekly basis.

d) A Special Meeting would be convened in the last week of September 2021(tentatively on 21.09.2021) to decide upon further course of action.

e) The NEW RSD Procedure and communications in this regard from SRPC is at Annexure-Oi.1.2.vi.e.

1.3 Subsequently, the Trail of New RSD Procedure implementation was discussed in the OCC meetings and in the 183rd meeting it was agreed to continue the trial till 31st December 202. ( i..e trial from 01.08.2021 to 31.12.0221 with full commercial implication).

Oi.2 Outage certification of RPC certified interstate lines

a) Since January 2018 onwards certification of the outage hours of Intra – State lines (Non-ISTS) certified by SRPC is being carried out by SRLDC. In the CERC (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020 there is no mention of RPC certified intra state transmission lines. In the 175th OCC Meeting after deliberations the following were decided:

b) From the date of Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020 came in effect (01st November 2020), outage certification by SRLDC & availability certification by SRPC would be carried out for the Non-ISTS lines approved by CERC as being used for Inter-State transmission of electricity.

c) The licensees of Non-ISTS lines may approach CERC for approval of Non-ISTS lines as being used for Inter-State transmission of electricity for sharing transmission


charges in line with CERC (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020. The list of Non-ISTS lines approved by CERC would be furnished to SRLDC/SRPC by the owner/licensee of the lines.

d) States to continue furnishing of outage data of the lines to SRLDC on monthly basis as per the practice being followed since 2018.

e) Outage/availability certification of natural ISTS lines (state owned lines crossing natural boundaries of two states) would be continued in line with other ISTS lines

Oi.3 Flexible operation of Nuclear Power Plants

A meeting was held under the Chairmanship of Hon’ble Minister of Power and New & Renewable energy on 16.09.2021 to discuss” Flexible Operation of Nuclear Power Plants”. The minutes of the meeting were issued vide letter dated 13th October 2021 (Annexure-Oi.3). Hon’ble Minister concluded that the 22,00 MW of Nuclear Power envisaged by 2031 can be accommodated as base load as the country makes the transition towards providing power through clean and renewable energy. In future, the deigns of nuclear power reactors should be such that there is flexibility of operation to accommodate the increasing renewable energy power. However, all care must be taken to ensure that safety is not compromised.

Oi.4 Items requiring attention of TCC/SRPC

i. Southern Region met till date maximum demand of 58430 MW on 02.04.2021 and till date maximum consumption met 1252.33 MU on 03.04.2021.

ii. Cyber Security audit of IT & OT systems to be conducted by CERT-ln empanelled agencies once in six months

iii. NLCIL has declared commercial operation of NNTPS Unit- II (500 MW) from 10.02.2021.

iv. Badradri Thermal Power Station Unit No-III ( 270 MW) was commissioned by TSGENCO on 26.03.2021

v. Black Start Restoration Procedure of Southern Region 2021 was released by SRLDC on 29.01.2021.

vi. CEA has published Technical Specifications for Bird Flight Diverter which is at CEA website. In SR Tuticorin area issues are being faced.

vii. The Application Tools for Interface (API) for SRLDC WBES for accessing real time data is introduced by SRLDC honoring requests from states. Two applications have been developed one for schedule and one for URS.

viii. PGCIL and SRLDC have arranged training program on URTDSM Phase-I on 01st& 02nd February 2021(by SRLDC) and on 03rd& 04th February 2021 by PGCIL/IIT Bombay.

ix. CEA has published Procedure for approval and facilitating Import/Export (Cross Border) of Electricity by the Designated Authority in line with Ministry of Power, Govt. of India "Guidelines for Import/Export (Cross Border) of Electricity-2018" and MoP OM dated 24th December, 2018.


x. MoP has notified the Electricity (Late Payment Surcharge) Rules, 2021 on 22.02.2021.

xi. MoP has notified Central Transmission Utility of India Limited, a Government Company as the 'Central Transmission Utility' and POWERGRID as 'Deemed Licensee' under Electricity Act. This notification came into force from 1st April, 2021.

xii. MoP has issued Guidelines vide communication dated 22.03.2021 for enabling DISCOMs to either continue or exit from the PPA after completing the terms of the PPA beyond 25 years or the period specified in the PPA and allow flexibility to the generators to sell power in any mode after state exits from PPA.

xiii. CERC vide Order dated 31.03.2021 has extended Pilot on Security Constrained Economic Dispatch (SCED) till 30th September 2021.

xiv. First meeting of the ‘Standing Committee on Communication System Planning in Power Sector’ was conducted by the Central Electricity Authority on 9th March, 2021

xv. CEA has launched RE dashboard on 21st April 2021in collaboration with Council on Energy, Environment and Water (CEEW). Detailed information of in respect RE plants in the country would be available on the dash board.

xvi. MoP has approved the Standard Specifications and Technical Parameters for Transformers and Reactors (66 kV & above voltage class) prepared by CEA which is available at CEA website. All stakeholders across the country is requested for adoption of the document.

xvii. 400 kV JSW - BTPS and JSW - Guttur lines outage were taken on 28th March, 2021 and delinking of 400 kV JSW – BTPS - GUTTUR Loop in Loop Out was carried out.

xviii. Reactive power testing at Pavagada was carry out on 16.02.21 (1 MVAR per 50MW Block) and 17.02.21(1 MVAR per 50MW Block).

xix. SPS of Talcher - Kolar TK-1, TK-2 and TK-3 and Raichur- Sholapur signals were disabled on 26.02.2021. TK -1 & TK 2 are wired to RP-I.

xx. PGCIL SR-I vide E-mail dated 26.02.2021 had informed that they have disarmed the SPS Schemes of 765 kV Raichur – Sholapur lines at 13:00 Hrs on 26.02.2021 vide Codes SR/3920 & NL/2380.

xxi. Bypassing of one ckt. of Neyveli TS-II - Salem 400 kV D/c line of GCIL and Neyveli TSII-NNTPS 400 kV S/c line of PGCIL at Neyveli TS-II, to form NNTPS-Salem 400 kV S/c line (agreed in 42nd SCPSPSR– to be implemented under ISTS) was carried out on 01.03.2021.

xxii. A meeting to discuss transmission issues pertaining to Andhra Pradesh and Karnataka was convened by CEA on 19.05.2021. Minutes of the meeting has been circulated to the concerned utilities. It was observed that there were coordination issues between TRANSCOs and GENCOs. The constituents may note that any transmission system for evacuation of the power from generation projects or any system strengthening scheme needed to be discussed and approved by SRPC(TP). Any kind of post-facto ratification should be avoided. All the utilities to put up the proposals in the planning stage itself for discussion/approval in SRPC(TP) meetings. Metering schemes also needed to be finalized in coordination with SRPC/SRLDC in time to avoid issues after commissioning.


xxiii. MoP vide Order dated 20.05.2021has circulated Amendment to the Order on Constitution of National Committee on Transmission vide Order dated 04.11.2019. Major highlights are CMD POSOCO will be a member of the Committee, cost aspects of the transmission schemes also would be studied etc.

xxiv. CEA has published Concept Paper on Insulated Cross Arm in May 2021. This may help to address the issue of RoW in congested/urban/wildlife areas. It is informed that a reduction of upto 20% in RoW is possible with the suggested arrangement/technique. Constituents may take note of the concept paper.

xxv. CEA has brought out a document on “Standard Technical Specification of Power Transformers for Solar Park Pooling Station (available at CEA website). This document will certainly help in the proper design and standardization of specification of transformers in Solar generation pooling station leading to quality and reliability, faster delivery and the uniform practice across the utilities in the country. This document may be used by all the concerned stake holders to make the vision of ‘One Nation, One Specification’ a reality.

xxvi. MOP vide Order dated 21.06.2021 ( available at MoP website) has amended the Order on Waiver of inter-state transmission charges on transmission of the electricity generated from solar and wind sources of energy dated 15.01.2021 regarding waiver of Inter-State Transmission system (ISTS) charges on transmission of electricity generated from solar and wind sources projects.

xxvii. MoP: Testing power system equipment for use in the Supply System and Network in the country for Cyber Security: MoP vide Order dated 08.06.2021 has communicated that Central Power Research Institute (CPRI) is hereby notified as the nodal agency for testing power system equipment for use in the Supply System and Network in the country for Cyber Security. The designated laboratories and the products for which cyber security conformance testing is to be undertaken on payment of applicable test charges are furnished. The protocols to be followed for testing the products for cyber security conformance testing, testing criteria and details of type tests are also furnished.

xxviii. MoP vide Notification dated 28.06.2021 had Amended Electricity (Right of Consumers) Rules 2020 and this will be called as Electricity (Right of Consumers) Amendment Rules 2021.

xxix. MoP vide letter dated 05th July 2021 has issued clarification on the clause 2(VIII) of the Guidelines on enabling the Discoms to either continue or exit from the PPA after completion of the term of the PPA i.e beyond 25 years or a period specified in the PPA and allow flexibility to the Generators to sell power in any mode after State/Discom exit from PPA.

xxx. MoP vide Resolution dated 10th August, 2021 has notified Guidelines for Encouraging Competition in Development of Transmission Projects

xxxi. CEA has issued Amendment No.1 to “Standard Specifications and technical Parameters for Transformers and Reactors (66 kV & above voltage class)”. Standard Specifications and technical Parameters for Transformers and Reactors (66 kV & above voltage class duly approved by Hon`ble Minister of Power and New and Renewable


Energy was circulated by CEA vide letter dated 29.04.2021 to all the concerned utilities. Clause No. 7 of Chapter 2 of the document which mandates the requirement of Dynamic Short Circuit Test for Transformers had been amended. The same is available at CEA website.

xxxii. MoP vide Office Order dated 20th October 2021 has dissolved five “Regional Power Committees (Transmission Planning)” (RPCTPS).Regional level consultation for ISTS planning will be done in Regional Power Committees. The constitution and terms of Reference of Regional Power Committees will be modified separately.

xxxiii. MoP vide letter dated 22nd October 2021 has communicated certain decisions regarding optimum utilization of power generated/ allocation of Central Generating Stations.

xxxiv. MoP vide Notification dated 22nd October 2021 has notified the Electricity (Timely Recovery of Costs due to Change in Law) Rules, 2021.

xxxv. MoP vide Notification dated 22nd October 2021 has notified Electricity (Promotion of Generation of Electricity from Must Run Power Plant) Rules, 2021.

xxxvi. MoP vide Office Order dated 22nd October 2021 has Re-constituted the "National Committee on Transmission" (NCT).

(ii) Commercial

Ci.1 Outstanding dues between Southern & Western Regional Constituents

1.1 Outstanding dues between Southern & Western Regional Constituents were under deliberation in various sub-committee meetings of SRPC and meetings with WR constituents.

1.2 The status is as follows:

SR Constituents

WR Constituents

Receivable from Payable to

MPPMCL*

(Rs.)

CSPDCL #

(Rs.)

CSPDCL #

(Rs.)

APTRANSCO / TSTRANSCO

1,21,76,270

KPTCL/PCKL 13,27,208

KSEBL 1,21,47,260 7,05,279

TANTRANSCO 1,17,17,268 92,77,878

* Madhya Pradesh Power Management Company Limited (MPPMCL) # Chhattisgarh State Power Generation Company Limited (CSPDCL)

1.3 In the 37th meeting of TCC held on 28.08.2020, MS, SRPC had informed that as per the Minutes of 83rdCCM of WRPC (11.09.2020), WRPC had requested that the old issues should be consolidated and finalized among all the WR beneficiaries first and a meeting can be


arranged with OPTCL & ERPC. He further had informed that pending payments between WR & SR utilities would be taken up subsequently.

1.4 In the Commercial Sub-Committee meetings, it was noted that the issue is under deliberation in Commercial Sub-Committee meetings of WRPC. Further course of action may be decided based on the outcome of the WR meetings.

1.5 KSEBL vide letter dated 22.07.2021(refer Annexure-O.19.1) requested that SRPC may kindly facilitate a meeting with MPPMCL, CSPDCL and Odisha Power Transmission Corporation Ltd. (Erstwhile GRIDCO) along with WRPC & ERPC for settling long pending issues.

This may please be noted.

Ci.2 Implementation of Automatic Meter Reading (AMR) in Southern Region

2.1 In the earlier meetings, the following were noted:

i) 24th Meeting of SRPC (15.03.2014): SRPC had approved implementation of the AMR scheme by PGCIL. Subsequently, the implementation of AMR in SR had been discussed in various Sub-Committee meetings and SRPC meetings.

ii) 37th meeting of SRPC (01.02.2020): SRPC had approved estimate cost of Rs. 36.86 Cr furnished by PGCIL for implementing AMR scheme in SR.

iii) 37th TCC meeting (28.10.2020): PGCIL was requested to expedite the finalization of the technical specifications and implement the AMR scheme at the earliest.

iv) In the 38th Meetings of SRPC (23.12.2020), the following were noted: a) In the meeting held on 19.11.2020 chaired by Chairperson, CEA with the participation

from PGCIL, CTU, POSOCO, RPCs etc. on the subject of Telemetry of real time Active Power (MW) data to SLDCs, it was decided to constitute a committee for finalizing the Technical Standards (TS) for AMR. The finalized TS would put to NPC for approval. It was agreed for pilot project by Gujarat and Rajasthan STUs to provide additional energy meters in series with the existing SEM. The cost would be borne by the respective STUs.

b) NPC Division, CEA vide letter dated 02.12.2020 had intimated that a joint committee comprising the members from each RPC, CEA, CTU/PGCIL & POSOCO had been constituted “to prepare the Technical Specifications (TS) of the 5/15 Minute Interface Energy Meters (IEMs) with Automatic Meter Reading (AMR) and Meter Data Processing (MDP) for interstate transmission system may be prepared at PAN India basis”.

c) In the 38th Meeting of TCC (22.12.2020), it was decided that after the finalization of Technical Specification by the Joint Committee, PGCIL would implement AMR in SR expeditiously.

2.2 CEA vide letter dated 28thJanuary 2021 has furnished the draft Technical Specifications (TS) for the 5/15 Minute IEMs with AMR/MDP and requested the members for views/ comments. First meeting of the Joint Committee was held on 05thFebruary 2021 wherein it was suggested


that RPCs to have deliberation on the TS with constituents and then the consolidated comments of RPCs on the draft TS may be forwarded to the NPC Secretariat.

2.3 Accordingly, a meeting was conducted with SR constituents on 08.04.2021 to discuss the draft Technical Specifications of 5/15 Minute Interface Energy Meters (IEM) with Automatic Meter Reading (AMR) /Meter Data Processing (MDP) for Interstate Transmission system and to finalize the consolidated comments of SR constituents (Rerecord notes of the meeting at Annexure- Ci.2.3).The consolidated comments of SR constituents on the draft Technical

Specifications were furnished to NPC Division, CEA on 14.04.2021 for consideration by the Joint Committee.

2.4 A Meeting of the Joint Committee for IEM and CDCS Technical Specification under the Chairmanship of Chairperson, CEA was held on 14.04.2021 through VC and the following are the major decisions:

i. 5/15 minute Energy accounting data shall be transmitted directly to RLDC. However, modalities for real time MW data streaming to SLDC with technical details shall be deliberated and finalized by the Joint Committee/RPCs. Further, RPCs may explore to house the servers in RPC secretariat being in proximity with RLDCs utilising the communication facilities available at RLDCs.

ii. Responsibility of Operation & Maintenance of IEM & DCU and CDCS & MDP may be as per CEA metering Regulations. Implementation methodology shall be finalized by RPCs.

2.5 3rd Meeting of Joint Committee for IEM and CDCS Technical Specification was held on 16.07.2021. Minutes of the meeting is at Annexure- Ci.2.5.


Ci.3 Assessment of ramping capability of thermal Inter-State Generating Stations (ISGS)

3.1 NLDC vide letter dated 28.02.2020 had issued the final detailed guidelines for assessment of ramping capability of thermal Interstate generating stations wherein it is stated that a statement of summary of calculations shall be prepared by respective RLDCs and certified by RPCs, at the end of each month of the financial year on cumulative basis, which shall indicate the ramping performance evaluation of each coal/lignite ISGS based on the metrics specified in these guidelines along with recommendation for change in rate of return of equity. The statement shall be posted on RPCs’ websites for information of all stakeholders.

3.2 SRPC vide letter dated 29.06.2020 had certified the statement of summary of calculations of ramping performance of thermal ISGS of Southern Region up to the month of April 2020 (for FY 2020-21) based on the data furnished by SRLDC vide letter dated 26.06.2020.

3.3 SRLDC vide e-mail dated 27.07.2020 had communicated that NTPC had raised concerns with CERC staff wrt Ramp scheduling and certification subsequent to April Month certification by RLDCs. A meeting in this regard was held between NTPC, CERC Staff and POSOCO on 15.07.2020 whereby CERC staff had suggested NTPC and POSOCO to mutually come out


with a solution and inform CERC. It was also told to hold the certification till then. POSOCO and NTPC was under discussion and once the solution is finalized and intimated to CERC shortly the certification for remaining months would be done.

3.4 In the 45th Meeting of Commercial Sub-Committee held on 28.08.2020, SRLDC had informed that the procedure for assessment of ramping capability of thermal Interstate generating stations is under modification by NLDC. The modified draft procedure would be published on NLDC website shortly for comments from stake holders.

3.5 The issue was further deliberated in the 37th TCC meeting held on 28.10.2020, wherein NLDC was requested to expedite the finalization of modified procedure for assessment of ramping capability of thermal ISGS.

3.6 Subsequently, NLDC vide letter dated 02.11.2020 had issued the proposed amendment to detailed guidelines for assessment of ramping capability of thermal Inter-state generating stations (ISGS) and requested to share the suggestions/feedback by 16th November, 2020.

3.7 NLDC vide letter dated 30.12.2020 has issued the revised final guidelines for assessment of ramping capability of thermal Inter-State Generating Stations on 30.12.2020 (Available at POSOCO website).

3.8 SRLDC vide letter dated 05.02.2021 has furnished the Ramp Performance of Thermal Power Stations in SR up to the month of December 2020. NLDC vide email dated 11.02.2021 has communicated that if the absolute scheduled ramp is less than 0.1 MW in any time block, it may be treated as 0 MW for the purpose of computation under the ramp assessment guidelines.

3.9 SRPC has been certifying the statement of summary of calculations of ramping performance of thermal ISGS of Southern Region on monthly basis based on the data furnished by SRLDC and assumption communicated by NLDC and the certified copies of the Ramping performance of Thermal ISGS of SR is made available at SRPC website.


Ci.4 Regional Transmission Deviation Account (RTDA) as per Sharing Regulations 2020

4.1 CERC (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020 came into force w.e.f 01.11.2020. Regulation 12 stipulates as below:

Quote:

12. Transmission Deviation: (1) Transmission Deviation, in MW, shall be computed as under:

(a) For a generating station, net metered ex-bus injection, in a time block in excess of the sum of Long Term Access, Medium Term Open Access and Short Term Open Access:

Provided that for a hydro-generating station, overload capacity of 10% during peak season shall be taken into account.

(b) For a State net metered ex-bus injection or net metered drawal, in a time block, in excess of the sum of Long Term Access and Medium Term Open Access.


………

Unquote:

4.2 Accordingly, Transmission deviation is computed in RTDA as below:

i) Transmission Deviation(MW) for a generating station(CGS or others) in a time block =

Net metered exbus injection – (LTA+MTOA+STOA)

ii) Transmission Deviation (MW) for a State in a time block =

Net metered drawal – (LTA +MTOA)

Note: LTA of a state includes the LTA exempted for Renewable Energy Generation of respective state as furnished by Implementing Agency.


(iii) Protection

P(I).1 Compliance of PCSC recommendations

Past Reference: PCSC meetings held during January – July, 2021 [PCSC-94 to PCSC-98]

1.1 All trippings involving 220 kV & above system on account of mal-operation/ non-operation of protection systems in place are regularly discussed in the Meetings of Protection Coordination Sub-Committee (PCSC) of SRPC with a view to identify their root cause and scrutinize correctness of operation of protection systems put in place by the concerned Constituents. In the process, appropriate measures required to be taken for system improvement are being suggested/ recommended for compliance by concerned Constituents.

1.2 PCSC had suggested / recommended appropriate measures, required to be taken for system improvement, for compliance by constituents concerned. The constituents were also requested to report the compliance/action taken on the suggestions/recommendations of the PCSC in the subsequent meetings. These PCSC recommendations, which are yet to be complied with, are circulated regularly, vide (i) Agenda & Minutes of PCSC meetings, and (ii) e-mails. In each PCSC meeting, brief discussion on status of Pending PCSC recommendations of previous meeting is discussed and updated by SRPC constituents.

1.3 The detailed status of pending implementation of PCSC recommendations had been compiled and kept available on SRPC web site (as Annexure to Minutes of the Meeting (MoM) of PCSC). It was requested that Utilities concerned may take concrete and definite action in complying with the pending PCSC recommendations.

1.4 In this regard, the following essential features, which ensure healthiness of protection systems put in place, are brought to the attention of all concerned for kind implementation:

a. Provision of Numerical Relays for protecting transmission lines, transformers, line/bus reactors &busbar at 220 kV &above voltage level, and generating units at all voltage levels.


b. Ensuring time-synchronization of various Protection Relays with GPS at all 220 kV & above stations.

c. Configuring Disturbance Recorder (DR) and Event logger (EL) for all requisite/ mandated protections & signals.

d. Ensuring multi-bus operation with zone-segregation at all 220 kV & above stations.

e. Ensuring healthiness of DC system (Protection & Communication).

f. Ensuring proper maintenance of transmission lines and adopting best O&M practices.

g. Ensuring earth-mat integrity & removal of DC leakage in the switchyard.

h. Adoption of stipulated Over-Voltage gradings for all 400 kV & above transmission lines.

i. Ensuring protection philosophy followed is in line with the Ramakrishna Committee guidelines.

j. Ensuring furnishing of tripping files (FIR/DR/EL/TR) within 24-hrs of the occurrence of a tripping event as per IEGC Regulation 5.2 (r) & regular attendance to PCSC meetings.

Put up for information of the forum please.

P(I).2 Adoption of New Over Voltage Relay (OVR) Gradings for 400 kV and 765 kV Transmission Lines of Southern Region

2.1 In the past one year, a number of new 400 kV and 765 kV transmission lines have been added to SR-Grid in addition to reconfiguration (including LILO) works of the existing 400 kV and 765 kV transmission lines. In this regard, a comprehensive exercise of OVR grading for 400 kV and 765 kV transmission lines of Southern Region (existing as of March, 2021 and few lines expected to come up in April – May, 2021) has been carried out, and 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 16.03.2021.

2.2 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 no: SRPC/SE-III/OVR/2021/778-811 dated 29.03.2021 for implementation with immediate effect, and confirm the same by 10.04.2021. The above OVR gradings have also been kept in SRPC Website for easy reference.


P(I).3 Review of Existing Islanding Schemes (IS) and Design of New Islanding Schemes in Southern region

3.1 A meeting was held on 28.12.2020 by Ministry of Power (MoP), Govt. of India with the Officials of CEA, RPC’s, POSOCO & PGCIL to review Islanding Schemes in the country. In the meeting, Hon’ble Minister of State (IC) for Power and New & Renewable Energy,


Government of India, among other things, directed that the following points must be considered while designing the Islanding schemes:

i. Islanding schemes should be designed for all major cities of the country. If there is a need to establish a power plant in / around such a city for the purpose, the proposal for the same may be submitted for consideration of the ministry. Possibility of installation of storage system at such location may also be explored.

ii. All the strategic and essentials loads should be covered in the Islanding schemes. For finalization of strategic loads, Ministry of Defence may also be consulted.

iii. Generating Stations, which are spatially nearby the strategic and essential loads, shall be given priority in designing the Islanding schemes.

In the meeting, SRPC was advised to quickly design the Islanding scheme for Bengaluru and get it implemented.

3.2 Secretary (Power), MoP convened a meeting on 31.03.2021 to discuss the planning alternative transmission access to Metro cities (including islanding scheme), on 31.03.2021. The following decisions were taken in the meeting:

i. CEA shall identify the cities, where islanding schemes would be required, by 10th April 2021. Ministry of Defence shall be consulted through MoP for identification of strategic loads.

ii. List of cites identified shall be divided in two categories. Category "A" shall contain list of those cities that are already having islanding schemes implemented for them, in one form or the other. Category "B" shall contain list of those cities where currently no islanding scheme is there.

3.3 MoP had taken another meeting on 16.04.2021 in which CEA/ RPC’s were asked to prioritise Cities/ Sites of strategic loads (esp. Defence), and come up with a limited but feasible Islanding Schemes.

3.4 In pursuance of above MoP directions given in 28.12.2020 meeting, SRPC initiated the review & finalization of all In-Service Islanding Schemes (Hyderabad IS, Chennai IS, Neyveli IS & Kudankulam IS) and Under-Implementation Islanding Scheme (Visakhapatnam IS) in January, 2021, and design of a new Islanding Scheme for Bengaluru metropolitan area in February, 2021.

3.5 Further, in pursuance of MoP directions given in 31.03.2021 & 16.04.2021, a meeting was conducted by SRPC on 15.04.2021 with all SR Utilities to identify all major cities (with population greater than one million as per Census-2011), and important sites of Defence installations in SR so that the same can be covered in either one of the existing Islanding schemes or by devising new Islanding Scheme.

In the meeting, the following Major Cities/ Sites of Defence Installations were observed to have been covered in one or the other In-Service/ Operational Islanding Schemes (Category-A) of SR:

Hyderabad, Chennai, Arakkonam, Coimbatore, Thanjavur, Madurai & Trivendrum

And the following Major Cities/ Defence Installations were proposed to be covered in the existing In-service Islanding Schemes or by devising new Islanding Schemes (Category-B) of SR:


Visakhapatnam, Vizianagaram, Bengaluru, Mysore, Karwar, Vijayawada, Kochi & Palakkad

3.6 Summary-status of various Islanding Schemes (IS) of Southern Region (SR) is as follows:

SN Name of the Islanding Scheme (IS)

Operational IS/ New IS

Status of the Review/ Design of the IS

Implementation Status of the Reviewed/ Designed IS

1 Hyderabad (Ramagundam) IS

(Telangana)

Operational IS Review: Completed on 05.03.2021.

Reviewed Scheme put into service w.e.f. July, 2021.

2 Chennai IS

(Tamil Nadu)

Operational IS Review: Completed on 18.05.2021

Implementation: Targeted by December, 2021.

3 Neyveli IS

(Tamil Nadu, Kerala)

Operational IS Review: Completed on 04.06.2021

Reviewed Scheme put into service w.e.f. 01.11.2021.

4 Kudankulam IS

(Tamil Nadu, Kerala)

Operational IS Review:

Targeted by

July, 2021

Implementation: Targeted by November, 2021

5 Visakhapatnam (Simhadri) IS

(Andhra Pradesh)

New IS Design: Completed on 27.04.2021

The finalized Scheme put into service w.e.f. July, 2021.

6 Vijayawada IS

(Andhra Pradesh)


The finalized Scheme put into service by November, 2021.

7 Bengaluru IS

(Karnataka)


Implementation: Targeted by December, 2021

3.7 Implementation Status of Islanding Schemes of Southern Region:

There are four islanding schemes in operation namely, Hyderabad (Ramagundam) IS, Chennai IS, Neyveli IS & Kudankulam IS and three newly designed, namely, Vishakapatanam (Simhadri) IS, Vijayawada IS & Bengaluru IS. As a result of the comprehensive exercise undertaken during February – August, 2021, these seven Islands schemes are under various stages of implementation.

Even though review of Islanding schemes is being undertaken in SR periodically, the impetus to the latest round of review exercise came directly from Ministry of Power (MoP), Govt. of India. MoP is


closely monitoring the implementation of various Islanding schemes in India by regularly conducting meetings with the Officials of CEA, POSOCO and RPCs. As per the MoP meeting held on 19.09.2021, the action point of RPCs and other concerned entities are as follows:

1) It was decided for setting up of separate display of islanding schemes on SCADA of respective states LDCs/Sub SLDCs and RLDCs for real time monitoring of participating generators & critical loads (Action: RPCs/RLDCs/SLDCs).

2) The naming of the Islanding Scheme may be done in such a way that it reflects the very objective of Islanding Scheme (action: RPCs).

3) Categorization of Islanding schemes may be done based on Category I for major cities, sensitive generation for other strategic loads and Category II for remaining schemes(action: RPCs).

4) A monthly MIS report regarding the status of the islading scheme under Category I and II may be furnished by CEA to MoP, priority efforts be made towards updating/preparing category I schemes. MIS should also indicate timelines and progress against the timelines for making category I schemes upto date and fully operational (Action by NPC & RPCs).

3.7.1 W.r.t. Action Point-1 (Creation of SCADA Display to Monitor Vital Parameters of the Island), it is intimated that Since formation of an Island can take place at any time, monitoring of the following vital parameters, which have a significant effect on successful Island formation, is of paramount interest:

Anticipated/ actual Generation within the electrical boundary of the Island

Anticipated/ actual Load within the electrical boundary of the Island

Voltage, Frequency & Power Flows along the peripheral lines which are required to be tripped to form the Island

Details & Flows on the feeders & loads of various AUFR & df/dt stages present within the Island

Details & Flows on various RE feeders present within the Island.

These parameters are to be monitored in real-time basis in the Control/ Despatch Centre of the area by creating a dedicated page specific to the Islanding Scheme in the SCADA display. To accomplish this, provision should also be made, if required, for installing adequate measuring instruments (like PMUs) at suitable locations within the Island.

The SCADA page should prominently display the geographic/ SCADA map (voltage level wise) showing the electrical boundary of the Island. At the top of the Island map, equidistantly placed “tabs” may be shown to display the vital parameters of the Island, viz., Generation details with cumulative quantum, Load details with cumulative quantum, df/dt load details with cumulative quantum , AUFR load details with cumulative quantum, LI & Pumped loads with cumulative quantum, Islanding forming elements, RE generation with cumulative quantum, etc. These tabs should be always visible on the main SCADA page irrespective of the selected voltage level of the Island map. Upon clicking any of the tabs, a separate page should get


popped up, and show the corresponding tab details (list of element names & quantum of power flow, Voltage, etc.).

The above is a mandatory requirement specified by the Ministry of Power (MoP), Government of India, and the action in this regard is time-bound as given below:

Islanding Scheme Timeline for making available sought SCADA Display

Implementing Utility

Hyderabad IS November, 2021 TS-SLDC

Chennai IS November, 2021 TN-SLDC (Chennai LDC)

Neyveli IS November, 2021 TN-SLDC (Erode LDC)

Kudankulam IS December, 2021 SRLDC in coordination with TN-SLDC (Madurai LDC) & Kerala-SLDC

Visakhapatnam IS November, 2021 AP-SLDC

Vijayawada IS November, 2021 AP-SLDC

Bengaluru IS December, 2021 KA-SLDC

All implementing Utilities are requested to take necessary action in this regard, and intimate the same to SRPC Secretariat.

3.7.2 W.r.t. Action point 2 (Naming of Islanding Schemes), it was noted that almost all of the Islanding schemes of SR had been named to meet the suggested requirement. It was clarified that from now onwards, Hyderabad/ Ramagudam Islanding scheme shall henceforth be called as Hyderabad Islanding Scheme and Visakhapatnam/ Simhadri Islanding Scheme shall henceforth be called as Visakhapatanam Islanding Scheme.

3.7.3 W.r.t. Action point 3 (Categorization of Islanding Schemes) - the following were noted:

Out of the seven Islanding schemes, the IS designed to cater to metropolitan cities, viz., Hyderabad, Chennai & Bengaluru are hereby categorized as Category-I Islanding Schemes.

Similarly, Kudankulam Islanding scheme, which caters to major cities such as Madurai, Trichy, Trivendrum & Kochin, in addition to being generation sensitive, is also hereby categorized as Category-I Islanding Scheme.

W.r.t. the remaining three IS, TANTRANSCO opined that Neyveli Islanding scheme may be kept under Category II, and APTRANSCO suggested that Visakhapatanam & Vijayawada Islanding schemes may be kept under Category II.

Accordingly, Neyvely IS, Visakhpatnam IS & Vijayawada IS are hereby categorized a Category-II Islanding schemes.


3.7.4 Requirement of Participating Generators to revise their Over-Frequency & Under-Frequency Settings appropriately to support Island survival:

SRPC observed that the Islanding Scheme is the last resort of defense mechanism and would come into picture only after exhaustion of all pre-Islanding defence mechanisms such as SPS, ADMS, df/dt two stages & AUFR 4 stages. The Islanding schemes serve to isolate pockets of Grid with reasonably good LGB in worst contingencies so that they continue to operate, and also help in integrating the grid after cessation of all eventualities. Since an Island has been designed with pre-determined load –generation balance, ensuring the availability of anticipated generation and anticipated load within the Island is crucial to its survival post its formation. To accomplish this, uncertainties w.r.t. generation/ load have been kept to minimum by excluding AUFR loads, and df/dt loads, LI and pump mode loads and RE generation. Under Frequency and Over frequency settings are to be well tuned.

Since the Islanding formation frequency itself is 47.9 Hz, frequency excursions in the system frequency in the range 47.5 – 52 Hz are to be expected for a couple of cycles within the Island immediately after its formation (due ti change in system inertia & attendant low power number) before finally settling in the range 49.5 – 50 Hz. Since the regulations allow a frequency band of 5% below 50 Hz. And 3% above 50 Hz, to maintain integrity of Island and to vouch for its survival, it is essential that the participating generators cling on to the grid (do not trip), and extend support as the Island is on course to stabilization. Therefore, all participating generators should revise their U/f and O/f settings appropriately to meet this requirement. TRANSCO & GENCOs may take a lead in this regard to convey this message to all the generators coming under their control area, including IPPs, CPPs and any state embedded generators which are coming under the ambit of Islanding. ISGS generators are being informed from SRPC side. Confirmation on the implementation may be furnished to SRPC/SRLDC. Specific SRPC letters dated 01.11.2021 in this regard have also been addressed to all concerned for compliance.

3.7.5 Detailed status of various Islanding Schemes (IS) of Southern Region (SR) is given at Annexure-P-I.

3.7.6 In this regard, Standard Operating Procedure (SoP) circulated by NPC vide mail dated 12.10.2021 for compliance by various Utilities at regional level is given at Annexure-P-II.

3.7.7 Certification of Healthiness of Islanding Schemes:

In order that an Islanding Scheme in place comes to rescue during any major disturbance, it is essential to ensure healthiness of relays, communication channel and other equipment/ instruments involved in forming & stabilising the Island. In this regard, MoP/ CEA directed RPCs to collect information on the Healthiness of Islanding Schemes on monthly basis as per the prescribed formats from all concerned Utilities.

As per the Standard Operating Procedure for Islanding Scheme, healthiness of islanding schemes shall be confirmed by participating Generators as well as concerned transmission utilities and LDC’s for their respective portion in the monthly OCC meetings.


All Constituents as listed below were requested to submit certificate on Healthiness of Islanding Schemes on monthly basis – by the first week of every month (i.e. status for a month shall be sent before the 7th day of the succeeding month) to SRPC as per the formats, circulated vide SRPC letter dated 09 August, 2021.

Islanding Scheme Participating

Generator Utilities

Participating

Transmission Utilities

Participating

LDCs

Hyderabad IS NTPC-RSTPS TSGENCO,

TSTRANSCO,

PGCIL (SR-I),

TS SLDC, SRLDC

Chennai IS NPCIL (MAPS) TANGEDCO, IPPs

TANTRANSCO,

PGCIL (SR-II)

TN SLDC, SRLDC

Neyveli IS NLCIL, IPPs/ CPPs TANTRANSCO,

PGCIL (SR-II), PED, KSEBL

TN SLDC

KL SLDC, SRLDC

Kudankulam IS NPCIL (KKNPP), IPPs/CPPs, RE Gen

TANTRANSCO,

PGCIL (SR-II), KSEBL

TN SLDC

KL SLDC, SRLDC

Visakhapatnam IS NTPC-Simhadri

APGENCO,

APGPCL, IPP/CPPs

APTRANSCO,

PGCIL (SR-I)

AP SLDC

SRLDC

Bengaluru IS NTPC Talcher STPS, NPCIL (KGS), KPCL, UPCL

KPTCL, PGCIL (SR-II), TANTRANSCO

KAR SLDC

TN SLDC, SRLDC

Vijayawada IS APGENCO,

LANCO

APTRANSCO, PGCIL SR-I AP SLDC

SRLDC

P(I).4 Implementation of Protection Suite / Protection Management System (PMS) for Southern Region

Past Reference- Approval of SRPC in the 26thmeeting held on 20thDecember, 2014.

4.1 Based on the approval of SRPC in the 26thmeeting held on 20thDecember, 2014 at Visakhapatnam, implementation of Protection Management System in Southern Region [Web-based Management Software and Protection Setting Calculation Tool for Southern Region] has been undertaken through PSDF funding. The project has been awarded, through open bidding process, to M/s PRDC Pvt. Ltd. (PRDC) on 09.08.2017. The execution period for the Project is about 18 months from the date of placement of LoA (also called “Effective Date”), and is followed by an Extended Technical Services period of 5 years. The details of the project implementation including Milestone-wise status and the highlights of the project implemented so far are given at Annexure- P-III.

4.2 The Go-Live meeting of the PMS project was conducted by the Executive Committee of the PMS project with PRDC in attendance of PCSC-Members on 19.04.2021, 20.04.2021, 22.04.2021, 23.04.2021 & 03.05.2021, to verify and assess the readiness of PMS project for being operationalized. Majority of the features had been successfully demonstrated by PIA, and the shortcomings observed in the meeting were intimated to PIA vide SRPC letter dated


14.05.2021 for expeditious resolution by May, 2021.

4.3 Then, subsequently due to Covid-19 pandemic the closure of the pending remarks could not be pursued for two months. Then by conducting a few Review Meetings during August-October, 2021, the closure of most of the points has been ensured. PRDC is being closely pursued with for expeditious closure of all remaining pending points/ remarks.

4.4 As informed by PRDC, the Project is targeted to be operationalized by November/December, 2021.

4.5 Post Operationalization of PMS project, a three-day refresher training on various PSCT Modules is proposed to be conducted for the benefit of SR-Constituents during December, 2021.

4.6 For deriving full benefits out of PMS Project, SR-Constituents are requested to ensure that Protection Database (Relay Settings database hosted in PDMS and Network Database for PSCT for use in Local Desktops/ Laptops) is kept up-to-date by furnishing all requisite information on Network Modifications through DMNS plat form, and use all PSCT Modules thoroughly for conducting various studies.


VII. SRPC Secretariat

1. Reimbursement of annual expenditure of SRPC Secretariat

1.1. The following are the decisions in respect of expenditure of SRPC Secretariat:

In the first meeting of SRPC held at Chennai on 6th June 2006, it had been agreed that all the Members of SRPC would equally share the expenditure of SRPC Secretariat.

Further, in the third Meeting of SRPC held at Bangalore on 19th February 2007, it had been agreed that the constituents would reimburse annual expenditure of SRPC Secretariat in the beginning of the financial year, based on the figures to be intimated by SRPC Secretariat. It had also agreed that any surplus/deficits of a particular year would be adjusted in the subsequent financial year.

1.2. Based on the Budget Estimate (BE) for the financial year 2021-22, the reimbursement of annual expenditure for the year 2021-22 worked out and the Statement showing net amount payable by Member Utilities of SRPC for the year 2021-22, after adjusting the surplus/deficits of the previous period has been communicated to the members vide SRPC letter dated 14th July 2021. The status of payment is at Annexure- AE.

Members are kindly requested to ensure payment, wherever due.

2. Meetings conducted after the 38th meeting of SRPC

The list of meetings conducted after the 38th meeting of SRPC (23.12.2020) is at Annexure- MTG.

***

Supplementary Agenda for the 39thmeetings of TCC & SRPC Page 1 of 6

Southern Regional Power Committee Bengaluru

Supplementary/Additional Agenda for the 39th meetings of TCC & SRPC

Date & Time & of TCC Meeting: 03.12.2021(Friday) from 10:00 Hrs onwards

Date & Time & of SRPC Meeting: 06.12.2021(Monday) from10:30 Hrs onwards

Mode of the Meetings: Video Conferencing (WebEx)

I. Operation 1. URTDSM (PMU) Project in Southern Region (Refer Main Agenda No.O.2)

A. Update by APTRANSCO: APTRANSCO vide letter dated 16.11.2021(Annexure-OS.1A) has intimated that AP had

already communicated the feedback on satisfactory working of PMUs established under URTDSM Phase-I and the requirement of PMUs under Phase-II to PGCIL.

B. Renewal of Insurance of URTDSM Project:

(i) TSTRANSCO had expressed concern regarding the issues regarding renewal of Insurance of URTDSM project with PGCIL. This issue was deliberated in the 184th Meeting of OCC and decided in that meeting a Special Meeting was convened on 11.11.2021 with participation from the State Utilities, PGCIL & CTUIL. In the Special meeting, PGCIL and TSTRANSCO were advised to approach reputed insurance companies and have a thorough discussion on the various aspects of insurance clauses. The suggestions obtained by the insurance companies (whether readily package/customized package), at least two companies may be approached may be communicated SRPC Secretariat.

(ii) Subsequently, TSTRANSCO vide letter dated 17.11.2021(Annexure-OS.1B) has

requested PGCIL to arrange a meeting with insurance providers to discuss the issues related to insurance coverage of the equipments under URTDSM project at TS SLDC control centre and at various sites in Telangana control area.

2. Implementation of the modified SPS scheme for Kaiga ICTs (Refer Main Agenda No.O.7)

KGS vide letter dated 19.11.021 (Annexure-OS.2) has requested to expedite the process of

implementation of Stage-II of the modified SPS scheme for Kaiga ICTs at the earliest. Necessary coordination from KGS will be ensured.

3. Strengthening of 110 kV Konaje – Manjeswaram interstate Line (Karnataka Portion)( refer Main Agenda No.O.22)

Agenda Proposed by KPTCL (refer Annexure-O.19.1): KPTCL letter dated 13.08.2021 is at Annexure-OS.3


4. RE Rich States – Difficulty in dispatching RE generation, optimum Scheduling and dispatch of Energy in the State – Implementation of 4 Time Blocks gate closure and definition of “Grid Security”

Additional Agenda by APTRANSCO vide letter dated 23.11.2021 (Annexure-OS.4):

APTRANSCO has informed the following:

a) The time period i.e 3 Time Blocks gate closure given for modification of scheduled Inter State Generation (ISGS) in advance in WBES of SRLDC appeared to be too large for the RE Rich States like AP with wide and abrupt variations in RE generation. With this operational constraint and shortfall / surplus of generation in real time grid operation. SLDCs could not able to achieve optimum scheduling and dispatch of energy with considerable reduction in dispatching of RE generation due to freezing the CGS schedules before six time blocks will definitely mitigate the deviations to the large extent and also reduce the burden on Discoms end consumers. SRLDC shall support all SLDCs to revise the CGS schedules with two time blocks notice in case of large variations in RE generation.

b) High penetration of Renewable Generation (Solar & Wind) as per the State or Central Govt. initiatives and its huge and sudden variable nature during the real time operation compared to forecast have made the grid system going out of bounds (frequency and deviation limits) for which all SLDCs are served with violation notices many times from SRLDC.

c) Technical constraint Grid security is to be defined precisely in the Act regulations. Otherwise it would be difficult to substantiate grid operations of curtailment instructions from SLDCs in the interest of grid even when there is absolute need to do so a study shall also be made with all the constituents before introduction implementation of any new amended Rules and Regulations regarding the impact on various issues as above.

d) Therefore it is necessary to discuss on a single platform for deliberation of views by the different constituents to get a clarification form CEA/CERC/MoP on the terms of “Technical Constraint” and “Grid Security” and other clauses such as 5.2 (m). 5.2 (u). and 5.4.2 (a) and 6.4.7 of IEGC including reduction of gate closure time of ISGS to 4 Time Blocks. Unless certain terms issues as above are not defined/ clarified precisely, the stakeholders are taking different interpretations to suit their needs and these are becoming legal issues.


5. Evacuation of Power from 1 x 800 MW Power Plant (Stage-V) of APGENCO at Dr. NTTPS, Vijayawada with existing network

Additional Agenda:

i. APTRANSCO vide letter dated 16.11.2021 had informed that the commissioning works of 1x800 MW (Stage V) Unit of Dr. NTTPS are at final stage and APGENCO is planning to synchronize the Unit with oil firing on 22.11.2021. The scheme of evacuation was already approved in 41st Standing Committee on Power System Planning of SR held on


22.09.2017 with the replacement of High Ampacity Conductor on the existing 400 kV VTS-Sattenapalli TMDC line. The present proposal for evacuating the power without replacement of existing ACSR conductor with High Ampacity Conductor had been furnished to CEA on 13.07.2021, and was stated to be listed for deliberation in the Part-II of the 3rd SRPC (TP) Meeting, which is not yet convened. APTRANSCO had requested to permit to synchronize the Unit to the Grid through the existing evacuation scheme.

ii. Ministry of Power vide Office Order dated 20.10.2021 has dissolved the five RPC-TPs viz. Eastern Regional Power Committee (Transmission Planning), Western Regional Power Committee (Transmission Planning), Northern Regional Power Committee (Transmission Planning), Southern Regional Power Committee (Transmission Planning) and North Eastern Regional Power Committee (Transmission Planning) constituted by the Ministry of Power vide Office Order No.15/3/2017-Trans, dated 04.11.2019. Regional level consultation for ISTS planning will be done in Regional Power Committees.

iii. SRPC Secretariat has requested the Chief Engineer (Power System Planning & Appraisal Division-I), CEA vide letter dated 22.11.2021(Annexure-OS.5) to arrange a special

meeting at the earliest to discuss the request by APTRANSCO with the participation from concerned wings of APTRANSCO, CTUIL, SRLDC & SRPC.


6. Commissioning of 500MVA ICT-3 at Tuticorin substation

Additional Agenda by PGCIL vide letter dated 25.11.2021 (Annexure-OS.6):

PGCIL has stated the following:

(i) Tuticorin-II GIS substation had been established with 2x500 MVA, 400/230 kV transformers for evacuation of power from the RE generation in the vicinity. Under system strengthening scheme 500MVA 400/220kV ICT-3 along with associated 400kV & 220kV GIS bays was approved in 42nd SCPSPSR held on 27.04.2018 and 34th SRPC meeting held on 11.08.2018. Accordingly the ICT-3 along with associated GIS bays (400kV-2nos & 220kV-1no) is ready for commissioning since March’21.

(ii) Further, Common facility works were also allocated to POWERGRID under RTM through MoP OM dated 25.09.20. Completion of these works is getting delayed due to delay in GIS equipment supplies from abroad.

(iii) However, both ICTs are loaded with more than 80% of the transformation capacity due to increased wind power generation. In case of outage of any ICT, under N-1 contingency criterion, the available transformation capacity shall not be sufficient to meet out the load at Tuticorin GIS. Recently one ICT got tripped on 14.07.21 on operation of Bucholz, the other ICT also tripped on overcurrent protection making RE evacuation critical. It is to mention that more wind generation is expected from Dec’21, commissioning of ICT-3 is to be done to avoid such incidents.

(iv) Keeping in view the loading of existing two nos of ICTs, ICT-3 commissioning may be allowed to evacuate RE Generation to Grid.


ISSUE:

a) Clearance for charging of the ICT-3.

b) ICT-3 commissioning may be allowed to evacuate RE Generation to Grid.


II. Commercial

1. Issues Regarding Calculation of Inter State Transmission Charges for TANGEDCO by NLDC (Refer Main Agenda No.C.5)

Second meeting of the LTA Sub Group for formulating an objective methodology to be adopted for determining Long Term Access and Medium Term Open Access corresponding to capacity connected to ISTS in case of Generating Stations connected to both ISTS and intra-State transmission system (for which LTA was not granted by the CTU) was held on 22.11.2021 through VC. Record Notes of the Meeting is at Annexure-CS.1.

Recommendation of the LTA Sub-Group:

a) Following methodology was agreed in principle by the Sub-Group for ascertaining the adequacy of intra-STU Network to evacuate their share from a GS connected to both STU system & ISTS:

i) The intra-STU network planned and implemented at the time of commissioning of the concerned Central Generating Station (CGS) only to be considered.

ii) ISTS Network connected to CGS may be taken out of service and CGS may be left connected with intra-state transmission system (STU network) of home state. If the home state STU system is meeting the all the criteria as per the transmission planning criteria to evacuate their share, then that quantum may be considered for exemption in the computation of sharing of transmission charges.

iii) Latest ATC/TTC All India Peak Base Case may be used for this purpose.

iv) Ex-Bus Firm + Un-allocated quantum of the beneficiaries (i.e., 100% of CGS net capacity) to be considered to evaluate whether the home state STU system is capable of evacuating their share.

However, TANGEDCO has expressed the concern on considering only the originally approved transmission system and opined that it may be appropriate to consider the present Intra-State Transmission system connected to the Generating Station for evaluation of the capacity to be evacuated through Intra-State Transmission system for LTA exemption.

b) Following Generating Stations of SR connected to both ISTS and intra-State Transmission System have been considered and concluded as below:

SN Generating Station Observation Conclusion/Recommendation

1. NTPC Kudgi STPS LTA was granted by CTU These Generating Stations have not been considered

by the Sub-Group for 2 Neyveli New

Thermal Power LTA was granted by CTU


Station (NNTPS) ascertaining the adequacy of intra-STU Network to evacuate their share from

GS.

3 NTPC Simhadri STPS Stage I

CERC vide Order 30.03.2017 in Petition No. 291/MP/2015 has exempted LTA.

4 UPCL LTA was granted by CTU

5 NTPC Ramagundam STPS Stage I & II

In line with the agreed methodology, TSTRANSCO system is capable of evacuating Telangana share.

LTA may be exempted for Telangana for the quantum of its share from Ramagundam STPS Stage-I & II.

6 NTPC Ramagundam STPS Stage III

RSTPS Stage III was planned to evacuate fully through the ISTS.

LTA exemption may not be considered.

7 NLC TPS II Stage I In line with the agreed methodology, TANTRANSCO system is capable of evacuating Tamil Nadu share.

LTA may be exempted for Tamil Nadu for the quantum of its share from NLC TPS II Stage I.

8 NLC TPS II Stage II 400kV lines were identified for evacuation of power from NLC TPS II Stage II.

However, TANGEDCO submitted that the entire Tamil Nadu share from NLC TPS II Stage I & Stage II can be evacuated through their intra-state transmission system.

LTA exemption for Tamil Nadu may not be considered.

9 NTECL, Vallur TPS There was divergence of views as below:

TANGEDCO: The interconnecting line (400 kV Vallur TPS – NCTPS St II D/c line) was considered for evacuation of power from NTECL as well as the reliability.

CTUIL: The interconnecting line was planned as the ATS of

Case may be considered by TCC/SRPC.


NCTPS St-II and not in the evacuation scheme of NTECL Vallur TPS.

10 NPCIL, KKNPP KKNPP was planned to be evacuated fully through the ISTS.


11 NPCIL, Kaiga GS Stage-I & II

400 kV ISTS were planned for evacuation of both the stages and no intra-State transmission system was considered for evacuation.

LTA exemption for Karnataka may not be considered.

c) NPCIL MAPS Kalpakkam: Case may be considered by TCC/SRPC.

TCC/SRPC may like to deliberate.

2. Payment of outstanding by beneficiaries as on 18.11.2021

Additional Agenda by PGCIL vide letter dated 25.11.2021 (Refer Annexure-OS.5)

The outstanding dues position against bills raised by CTU towards POWERGRID dues under SR is given below: Rs. in Crores

Sl. No DIC Total Dues Dues> 45days 1 TNEB/TANGEDCO 531.24 176.37 2 BHAVINI (Non PoC) 153.08 151.03 3 TELANGANA 199.6 43.08 4 ANDHRA PRADESH 99.35 11.78 5 KSK MAHANADI(TNEB) 6.45 6.45 6 BESCOM 61.49 1.51 7 CESCOM 25.36 0.77 8 TANTRANSCO 0.41 0.41 9 APSPCL 0.37 0.32 10 KSEBL (Kerala) 59.6 0.20 11 GESCOM 12.99 0 12 HESCOM 24.57 0

POWERGRID’s SUBMISSION: DICs may be advised to clear the dues in time.

****

Annexure OS.1A (Page 1 of 12)












ANSCO TRANSMISSION CORPORATION OF TELANGANA LIMITED VIDYUT SOUDHA:: HYDERABAD - 82

Website:transco.telangana.gov.in CINNO.U40102TG2014SGC094248 From,

To The Chief Engineer, Pówer Grid Corporation of India Ltd, SLDC/ TSTRANSCO SRTS-1, No.6-6-8/32, Vidyuth Soudha, 395E,Kavadiguda Main Road, Hyderabad-82 Secunderabad-80

Lr.No.CE(SLDC)/SE(SLDC)/DE(DS&SCADA-ID/F.URTDSM/D.No. 1S /2021, Dt:.17.11.2021 Sir

Sub:-TSTRANSCO-SLDC -Insurance renewal for equipment under URTDSM project in Telangana Reg. Ref: 184" OCC-Special Meeting on URTDSM project insurance renewal issues, Dt: 11.11.2021

As per the Special meeting deliberations held on Dt: 11.11.2021, it is requested to arrange a meeting with M/s. PGCIL(URTDSM) & Insurance providers to discuss issues related to the insurance coverage of the equipments under URTDSM project at TSSLDC Control centre and at various sites in Telangana control area. The date & time of the meeting may be communicated to TSSLDC for deputing the concerned team.

It is also requested to provide the photo copy of last insurance along with the details of cost incurred on the various equipments (at control centre & sites) and its recovery mechanism covered under this project in Telangana.

Urgent action in this regard is essential as there is no insurance coverage to the

URTDSM Project.

Yours faithfully

1 Chief Engineer/StDC25 Vidyuth Soudha, Hyderabad

Copy submitted to:

1. The Director (Grid Operation) TSTRANSCo, Vidyutsoudha,Hyderabad.2. The Member Secretary, SRPC, 29, Race Course Cross Road, Bangalore-560 009.

3. The Executive Director /SRLDC/Bangalore.

Annexure OS.1B (Page 1 of 1)

संNo: केजीएस–1व2KGS-1&2/तसेअTSS/2021 /एस/S/ िदनांक Date : 19th November, 2021.

FOR: CHIEF ENGINEER, RT, KPTCL, BENGALURU – [email protected]

RPT: CHIEF ENGINEER, LDC, KPTCL, BENGALURU – [email protected]

RPT: SUPERINTENDENT ENGINEER, OPERATION, SRPC, BENGALURU - [email protected] RPT: SUPERINTENDENT ENGINEER, P & SS, SRPC, BENGALURU - [email protected] RPT: MEMBER SECRETARY, SRPC, BENGALURU - [email protected]

Sub: Implementation of Stage –II of the modified SPS scheme for Kaiga ICTs – reg

During the 81st PCSC Meeting held on 24.01.2019, a modified SPS scheme was proposed

for Kaiga ICTs (ICT 1 & 2) as given below:

Proposed SPS at 220 kV Kaiga Generating Station:

During non‐availability of one of the ICTs at Kaiga Generating Station, following stage wise

Protection will activate:‐

Stage‐ I: If the power flow in the other ICT (in service) is more than 500 MW and less than

530 MW, then a signal will be generated to give ALARM locally at Kaiga GS

(same as in existing SP).

Stage‐ II : If the power flow in the other ICT (in service) is more than or equal to 530 MW

and less than 550 MW, then suitable SPS signals will be generated at Kaiga GS

end, and are transmitted through PLCC to Kadra PH and Kodasalli PH using

which, latter will effect automatic generation reduction of about 50 MW (by

tripping the identified running Unit) at Kadra PH and of about 40 MW (by

tripping the identified running Unit) at Kodasalli PH (additional logic to be

incorporated )

Stage‐III: If the power flow in the other ICT (in service) is more than or equal to 550 MW

for 2 sec, then 220 kV Kaiga GS ‐ Kadra PH line and 220 kV Kaiga GS ‐ Kodasalli

PH line will be tripped from 220 kV Kaiga GS end (same as in existing SPS).

यूिक्लयर पाॅवर काप रेशन ऑफ इिंडया िलिमटेड NUCLEAR POWER CORPORATION OF INDIA LIMITED

(भारत सरकार का उद्यम Government of India Enterprise) कैगा िबजली उ पादन कद्र 1 व 2 KAIGA GENERATING STATION 1 & 2

राजेश जी. पाठक RAJESH G. PATHAK तकनीकी सेवाएं अधीक्षक TECHNICAL SERVICES SUPERINTENDENT

Corporate Identity No. U40104MH1987GOI49458 Telephone : 08382-264132 Fax :08382-264034

Mobile No. 09427111955 Email : [email protected]

कैगा थल ,कैगा‐581400, उ र क नड िजला, कनार्टक. Kaiga Site, Kaiga – 581400, U.K. District, Karnataka. पंजीकृत कयार्लय : 16वी तल, सटर-1, व ड्र् टे्रड सटर, कफे परेड, कोलाबा, मु बई- 400005. Registered Office : 16th Floor, Centre‐1, World Trade Centre, Cuffe Parade, Colaba, Mumbai‐400005.

Annexure OS.2 (Page 1 of 4)

यूिक्लयर पॅावर काप रेशन ऑफ इंिडया िलिमटेड

Nuclear Power Corporation of India Limited कैगा िबजली उ पादन कद्र, कैगा थल. Kaiga Generating Station, Kaiga Site.

At Kaiga end as a part of SPS, stage –I and stage –III of SPS was implemented and for

stage‐II of SPS a provision (Single ICT more than 500MWe for 5 Seconds) was made at

Kaiga end. KPTCL can extend the signal to Kadra and Kodasalli PH during ICT shut down

condition.

Also, during 184th OCC meeting, as per deliberation, KPCL was requested to update the

status of implementation like preparedness etc by 15.11.2021 and in coordination with

KPTCL, implementation is to be carried out by end of November2021 (copy attached).

It is requested to expedite the process of Implementation of Stage –II of the modified SPS

scheme for Kaiga ICTs at the earliest. Necessary coordination from Kaiga will be ensured.

आदर सिहत With regards.

(राजेश जी पाठक Rajesh G Pathak) तकनीकी सेवाएं अधीक्षक Technical Services Superintendent

प्रित

CC:

थल िनदे क Site Director

क.िन./मु.अ.– केजीएस –3व4 SD/CS - KGS 3&4

क.िन./मु.अ.– केजीएस –1व2 SD/CS - KGS 1&2

- सचूनाथर् - for kind information

सभी अधीक्षक, केजीएस –1व2 All Supdt. KGS 1&2

त.से.अ./विर.तक.अिभ.(ई एंड आई), केजीएस –1व2, 3व4/ TSS/STE(E&I)- KGS 1&2, KGS-3&4


Minutes of the 184th

meeting of OCC (10.11.2021) Page 29 of 71

12. Status of the implementation of the modified SPS scheme for Kaiga ICTs

(i) Implementation of the modified SPS scheme at Kaiga End is as follows:

Stage-I Implemented

Stage-II

Provision (Single ICT more than 500Mwe for 5 Seconds)

made at Kaiga End – Respective implementation agency can

extend the signal to Kadra and Kodasalli PH during ICT shut

down condition.

Stage-III Implemented

(ii) In the 182nd

OCC meeting, KPTCL had informed that they have taken up

with KPCL regarding the implementation of second stage and KPCL also

had concurred for the implementation. KPCLhad informed that the PLCC

wing also had confirmed that the signal can be extended for Stage II

Implementation.KPTCL informed that the implementation would be done

in three weeks’ time.

(iii) In the 183rd

meeting, KPCL informed that the PLCC communication is

ready and KPTCL may take up the implementation.KPTCL informed that

their SCADA is ready and the scheme would be implemented by the end

of October 2021.

(iv) In the 3rd

meeting of Southern Regional Power Committee (Transmission

Planning) the following had been noted during deliberation on ICT

constraints of 400/220 kV 2x500 MVA ICTs at Kaiga:

CGM, SRLDC added that KPTCL has to implement SPS to avoid the

tripping of ICTs at Kaiga S/s and subsequent tripping of generating

units at Kaiga during contingencies. However, SPS has not yet been

implemented. The implementation of modified SPS had been agreed

in January, 2019.

Member (Power System), CEA, advised KPTCL to complete the

reconductoring work at the earliest. He advised Member Secretary

(I/c), SRPC, to discuss and resolve the issues in implementation of

SPS with KPTCL.

Deliberation:

(i) SRPC observed that this is a long pending issue. The scheme was

approved in the year 2019.


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Excerpt of 184th OCC MOM

Minutes of the 184th

meeting of OCC (10.11.2021) Page 30 of 71

(ii) CGM, SRLDC informed that there was no updates from KPTCL nor

KPCL. He observed that since Stage III is implemented system is safe, but

all the lines from Kadra&Kodasalli will trip. Stage II will provide an

opportunity to KPCL to go for generation reduction and tripping of units

may be avoided. Karwar, Kodasalli and Kadrawill go into black out if

Stage II is not implemented.

(iii) SE, KPCL informed that in coordination with KPTCL the Stage II

implementation may be completed by end of November 2021.

(iv) KPCL was requested to update the status of implementation like

preparedness etc by 15.11.2021 and in coordination with KPTCL

implementation to be carried out by end of November2021.

13. IslandingSchemes of Southern Region

13.1 Implementation Status of Reviewed/New Islanding Schemes:

A. Islanding Scheme in operation (4 Nos.) Reviewed during 2021:

Sl No. Name of Islanding

Scheme

Implementation Status Stake-holding Utilities

(responsible for

implementing IS)

1.

Hyderabad IS Review completed on

05.03.2021 and the

scheme put into

service w.e.f July,

2021

TSTRANSCO,

TSGENCO,

PGCIL SR-I,

NTPC-RSTPS

2.

Chennai IS Review completed on

18.05.2021.

Implementation

expected by October,

2021

TANTRANSCO,

TANGEDCO,

PGCIL SR-II,

3.

Neyveli IS Review completed on

04.06.2021.

Implementation

expected by

September, 2021

TANTRANSCO,

PGCIL SR-II,

TANGEDCO,

NLCIL TS-II

NLCIL TS-II EXP,

NNTPS, KSEBL

4. Kudankulam IS

Review completed on

18.08.2021

Implementation

expected by

November, 2021

TANTRANSCO,

TANGEDCO,

PGCIL SR-II,

KSEBL






ईमेल/Email

Email: [email protected] www.srpc.kar.nic.in Phone: 080 -22282516

FAX: 080 -22259343

स.ं/No: SRPC/SE-III/PLG/2021/ दिन ंक/Date : 22.11.2021

सेव में/ To

Shri Ishan Sharan

Chief Engineer

Power System Planning & Appraisal Division-I

CEA, New Delhi

विषय/Sub: Evacuation of Power from 1 x 800 MW Power Plant (Stage - V) of APGENCO at

Dr. NTTPS, Vijayawada with existing network.– reg.

संदर्भ/ Ref: APGENCO communication dated 16.11.2021 (Annexure)

महोदय/ Sir,

APTRANSCO vide letter under reference had informed that the commissioning works of 1x800

MW (Stage V) Unit of Dr. NTTPS are at final stage and APGENCO is planning to synchronise the

Unit with oil firing on 22.11.2021. The scheme of evacuation was already approved in 41st

Standing Committee on Power System Planning of SR held on 22.09.2017 with the replacement

of High Ampacity Conductor on the existing 400 kV VTS-Sattenapalli TMDC line. The present

proposal for evacuating the power without replacement of existing ACSR conductor with High

Ampacity Conductor had been furnished to CEA on 13.07.2021, and was stated to be listed for

deliberation in the Part-II of the 3rd SRPC (TP) Meeting, which is not yet convened. APTRANSCO

had requested to permit to synchronize the Unit to the Grid through the existing evacuation

scheme.

In this regard, the following are brought to your notice:

1. MoP vide Office Order dated 20.10.2021 had dissolved five Regional Power Committees

(Transmission Planning); as such the second Part of the 3rd SRPC (TP) Meeting would not be

convened as planned earlier.

2. During discussion in the Special Meeting held on 18.11.2021 to discuss on the Draft

Procedure for Planning of Inter State Transmission System (ISTS) brought out by CTUIL,

APTRANSCO had raised this issue and SRLDC had expressed that they didn’t have any specific

issues in this regard; however, since it being a planning issue needed to be taken up with

CEA/ CTUIL. CTUIL had opined that since there is no clarity in the role of CTUIL in planning

Intra-State Transmission system and approval, APTRANSCO had to approach CEA for

approval.

भ रत सरक र

केन्द्रीय ववद्युत प्र धिकरण

िक्षिण िेत्रीय ववद्युत सममतत

29, रेस कोसस क्र स रोड

बेंगलूर :- 560 009

Government of India Central Electricity Authority

Southern Regional Power Committee

29, Race Course Cross Road BANGALORE - 560 009


3. It is noted that APTRANSCO had projected deficit in the coming months and at present

system demand is being met through high cost power purchase from RTM. APTRANSCO is

forced to impose load shedding on many occasions in the previous two months also. They

have planned the LGB considering the power from 800 MW of Dr. NTTPS Stage V,

commissioning of which is being held up due to evacuation issues.

It is requested that you may kindly look into these issues and in view of the urgency of the

matter, a special meeting may be arranged by CEA at the earliest to discuss the request by

APTRANSCO with the participation from concerned wings of APTRANSCO, CTUIL, SRLDC & SRPC.

Favourable decision in this regard at the earliest is highly appreciated.

भविीय/ Yours faithfully,

सलंग ्‍नक/Encl:‍यथोपरि /as above

(एन॰ आर॰ एल॰ के॰ प्रस ि / N.R.L.K. Prasad)

अिीिण अमभयतं (P&SS) /Superintending Engineer (P&SS)

प्रतिललवप/्Copy्to:

1. Chief Engineer (PS, Plg & Design), APTRANSCO, Vijayawada

2. ED, SRLDC, Bengaluru






Additional Agenda for 39th SRPC Meeting

1. Commissioning of 500MVA ICT-3 at Tuticorin substation

Tuticorin-II GIS substation had been established with 2x500 MVA, 400/230 kV transformers for evacuation of power from the RE generation in the vicinity. Under system strengthening scheme 500MVA 400/220kV ICT-3 along with associated 400kV & 220kV GIS bays was approved in 42nd SCPSPSR held on 27.04.2018 and 34th SRPC meeting held on 11.08.2018. Accordingly the ICT-3 along with associated GIS bays (400kV-2nos & 220kV-1no) is ready for commissioning since March’21. Further, Common facility works were also allocated to POWERGRID under RTM through MoP OM dated 25.09.20. Completion of these works is getting delayed due to delay in GIS equipment supplies from abroad.

However, both ICTs are loaded with more than 80% of the transformation capacity due to increased wind power generation. In case of outage of any ICT, under n-1 contingency criterion, the available transformation capacity shall not be sufficient to meet out the load at Tuticorin GIS. Recently one ICT got tripped on 14.07.21 on operation of Bucholz, the other ICT also tripped on overcurrent protection making RE evacuation critical. It is to mention that more wind generation is expected from Dec’21, commissioning of ICT-3 is to be done to avoid such incidents.

Keeping in view the loading of existing two nos of ICTs, ICT-3 commissioning may be allowed to evacuate RE Generation to Grid.

Forum may deliberate and accord clearance for charging of the ICT-3.

2. Payment of outstanding by beneficiaries as on 18.11.2021:

The outstanding dues position against bills raised by CTU towards POWERGRID dues under SR Region is given below:

Rs.in Crores

Sl. No. DIC Total dues Dues > 45days

1 TNEB/TANGEDCO 531.24 176.37

2 Bhavini (Non PoC) 153.08 151.03

3 TELANGANA 199.6 43.08

4 ANDHRA PRADESH (AP)

99.35 11.78

5 KSK MAHANADI(TNEB) 6.45 6.45

6 BESCOM 61.49 1.51


Sl. No. DIC Total dues Dues > 45days

7 CESCOM 25.36 0.77

8 TANTRANSCO 0.41 0.41

9 APSPCL 0.37 0.32

10 KSEB (Kerala) 59.6 0.2

11 GESCOM 12.99 0

12 HESCOM 24.57 0

TOTAL 1174.51 391.92

POWERGRID’s SUBMISSION

DICs may be advised to clear the dues in time.


E-mail

भारत सरकार क ीय िव तु ािधकरण

दि ण े ीय िव तु सिमित 29, रेस कोस ास रोड

बगलरू - 560 009

Government of India Central Electricity Authority

Southern Regional Power Committee 29, Race Course Cross Road

Bengaluru - 560 009

Web site: www.srpc.kar.nic.in Email: [email protected] Phone: 080-22287205

स/ंNo. SRPC/SE(C)/2021-22/ िदनांक /Date 25th November 2021

To

All Sub-Group Members as per the Mailing List

Subject: Second Meeting of the Sub-Group to formulate a philosophy on LTA quantum of the generating stations connected to both ISTS and intra-State transmission system -reg.

Madam/Sir,

Enclosed, please find Record Notes of the Second Meeting of LTA-Sub Group of SR to formulate a philosophy on LTA quantum of the generating stations connected to both ISTS and intra-State transmission system held on 22.11.2021.

Yours faithfully

(मेकारा मकृ ण/ MEKA RAMAKRISHNA)

अधी णअ भय ता(वा)/Superintending Engineer (C)

Mailing List:

1. Shri. P Ch Kondala Rao, EE, APTRANSCO([email protected]) 2. Shri.A V L K J Sharma, Dy.EE, APTRANSCO([email protected]) 3. Smt. P Jyostna Rani, EE, APTRANSCO ([email protected]) 4. Ms. Geetha, EE, KPTCL([email protected]) 5. Smt. Nikitha Achar, AO, KPTCL ([email protected]) 6. Smt. Savitri, JD,PCKL([email protected]) 7. Smt. Rekha R, DD, PCKL ([email protected]) 8. Smt. Latha S.V, AEE, KSEBL ([email protected]) 9. Shri. R Krishna Kumar, AEE, KSEBL([email protected]) 10. Shri. T. Subbarayan, SE, TANTRANSCO([email protected]) 11. Ms. R. Ramalakshmi, SE, TANGEDCO ([email protected]) 12. Shri. M.Sudarsan, SE, TANTRANSCO([email protected]) 13. Shri. P Suresh Babu, SE, TSTRANSCO ([email protected]) 14. Ms. V.Yashodhara Rani, SE, TSTRANSCO ([email protected]) 15. Puducherry ED ([email protected]) 16. Shri Anil Kumar Meena, Sr. DGM, CTUIL ([email protected]) 17. Shri V Srinivas, Sr. DGM, CTUIL ([email protected]) 18. Shri. Ravi Shankar C, CM, SRLDC([email protected]) 19. Shri. KBV Ramkumar, Manager, SRLDC ([email protected]) 20. Shri. Sanny Machal, Manager, NLDC([email protected])

Annexure CS.1 (Page 1 of 144)

Record Notes of Second Meeting of the LTA-Sub Group of SR held on 22.11.2021 1/13

SOUTHERN REGIONAL POWER COMMITTEE BENGALURU

Record Notes of the Second Meeting of the LTA Sub-Group held on 22.11.2021 through VC

I. INTRODUCTION 1. Second meeting of the LTA Sub Group for formulating an objective methodology to be adopted

for determining Long Term Access and Medium Term Open Access corresponding to capacity connected to ISTS in case of Generating Stations connected to both ISTS and intra-State transmission system (for which LTA was not granted by the CTU) was held on 22.11.2021 through VC. The list of participants is given at Annexure-I.

2. Superintending Engineer (Commercial), SRPC extended a hearty welcome to all the Sub-Group Members and participants to the second meeting of the LTA Sub-Group.

3. Shri. Naresh Bhandari, Member Secretary, SRPC welcomed all the Sub-Group members and other participants to the meeting. He stated that as decided by the TCC of SRPC in the special meeting held on 18.10.2021, a Sub-Group under SRPC Secretariat comprising the members from CTUIL, NLDC, SRLDC and SLDCs/STUs of Southern Region (SR) was constituted for finalizing the methodology to be adopted for determining LTA corresponding to capacity connected to ISTS in case of Generating Stations connected to both ISTS and intra-State transmission system for which LTA was not granted by the CTU. One Sub-Group meeting and one Joint Study meeting had been held so far. He informed that in the Third CERC interaction meeting with RPCs held on 17.11.2021, the issues in respect of CERC (Sharing of Transmission Charges and losses) Regulations 2020 had been apprised to CERC by RPCs wherein CERC has stated that a committee comprising members from NLDC/POSOCO, CTUIL, RPCs etc. would be formed to deliberate on various issues highlighted by the stakeholders. He observed that since the committee to be constituted by CERC would be discussing and resolving the issues on pan-India basis, the LTA Sub-Group of SR may conclude their deliberations in this meeting and the recommendations of the Subgroup may be put up to TCC in the ensuing meeting (scheduled on 03.12.2021).

II. BACKGROUND 1. As decided in the special meeting of TCC of SRPC held on 18.10.2021, a Sub-Group

(LTA-Sub Group) under SRPC Secretariat comprising the following Members from CTUIL, NLDC, SRLDC and SLDCs/STUs of Southern Region has been constituted vide SRPC letter no: SRPC/SE-I/2021-22 dated 25.10.2021 to formulate on Objective Methodology/ General Philosophy to be adopted for determining Long Term Access and Medium Term Open Access corresponding to capacity connected to ISTS in case of Generating Stations connected to both ISTS and intra-State transmission system and submit its recommendation to TCC within one month:

1) Shri. P Ch Kondala Rao, EE, APTRANSCO 2) Shri.A V L K J Sharma, Dy.EE, APTRANSCO



3) Ms. P Jyostna Rani, EE, APTRANSCO 4) Ms.Savitri, JD,PCKL 5) Ms.Rekha R, DD, PCKL 6) Ms. Geetha, EE, KPTCL 7) Ms. Nikitha Achar, AO, KPTCL 8) Ms.Latha S.V, AEE, KSEBL 9) Shri. R Krishna Kumar, AEE, KSEBL 10) Shri. T. Subbarayan, SE (LD&GO), TANTRANSCO 11) Ms. R. Rama lakshmi, SE (CERC), TANGEDCO

12) Shri. M.Sudarsan, SE(SS), TANTRANSCO 13) Shri. P Suresh Babu, SE, TSTRANSCO 14) Ms.V.Yashodhara Rani, SE, TSTRANSCO 15) Shri. Anil Kumar Meena, Sr. DGM, CTUIL

16) Shri. V Srinivas, Sr. DGM, CTUIL 17) Shri. Ravi Shankar C, CM, SRLDC 18) Shri. KBV Ramkumar, Manager, SRLDC 19) Shri. Sanny Machal, Manager, NLDC

2. Following are the Generating Stations in Southern Region which are connected to both ISTS and intra-State transmission system:

i) NTPC Ramagundam STPS Stage I &II ii) NTPC Ramagundam STPS Stage III iii) NTPC Simhadri STPS Stage I iv) NTPC Kudgi STPS v) NTECL Vallur TPS vi) NLC TPS II Stage I vii) NLC TPS II Stage II viii) Neyveli New Thermal Power Station(NNTPS) ix) NPCIL, Kaiga GS Stage I & Stage II x) NPCIL, KKNPP xi) UPCL

It may please be noted that NPCIL MAPS Kalpakkam is a Central Generating Station located in Tamil Nadu connected only through intra-State Transmission System (STU-TANTRANSCO).

3. In the First meeting of LTA Sub Group held on 28.10.2021, the following were agreed(Record Notes of the Meeting is at Annexure-II):

a) NTPC Kudgi STPS, Neyveli New Thermal Power Station (NNTPS), NTPC Simhadri STPS Stage I & UPCL are not required to be considered by the Sub-Group since LTA was granted by CTU/Specific CERC Orders.

b) The methodology for ascertaining the adequacy of intra-STU Network to evacuate their share from a CGS connected to both STU system & ISTS as below:



ISTS Network connected to CGS may be taken out of service and CGS may be left connected with intra-STS system of the home state. If the home state STU system is meeting all the requirements as per the transmission planning criteria to evacuate their share, then that quantum may be considered for exemption in the computation of sharing of transmission charges.

Studies to be carried out considering the intra-STU network planned and implemented at the time of commissioning of the concerned CGS.

Latest ATC/TTC All India Peak Base Case may be used for this purpose.

Ex-Bus Firm + Un-allocated quantum of the beneficiaries (i.e., 100% of CGS capacity) to be considered to evaluate whether the home state STU system is capable of evacuating their share.

c) CTUIL and respective SLDC/STU to provide the details of originally approved evacuation system for the following CGS for carrying out system studies:

i) NTPC Ramagundam STPS Stage I & II ii) NTPC Ramagundam STPS Stage III iii) NTECL, Vallur TPS iv) NLC TPS II Stage I v) NLC TPS II Stage II vi) NPCIL, Kaiga GS Stage I& II vii) NPCIL, KKNPP

d) NLDC/SRLDC, CTUIL & respective SLDC/STU to conduct the studies based on the agreed methodology and a joint study meeting would be conducted on 02.11.2021 for analyzing the study results.

4. In the Joint Study meeting held on 02.11.2021, the following were observed/concluded (Summary of the Joint Studies Meeting is at Annexure-III):

a) NTPC Ramagundam STPS Stage I & II: TSTRANSCO system connected to RSTPS is capable of evacuating Telangana share.

b) NLC TPS II Stage I: TANTRANSCO system connected to NLC TPS II Stage I is capable of evacuating Tamil Nadu share of NLC TPS II Stage I.

c) NTPC Ramagundam STPS Stage III:As per the Minutes of 9th Meeting of Standing Committee on Power System Planning in SR held on 04.12.1998(Relevant extract is at Annexure-IV), RSTPS Stage III was planned to be evacuated fully through the 400 kV ISTS and no intra-State transmission system was considered for evacuation.

d) NPCIL Kaiga GS Stage I & II:As per the Minutes of 16th Standing Committee on Power System Planning in SR held on 20.01.2003 (Relevant extract is at Annexure-V), only 400 kV ISTS were planned for evacuation of both the stages and no intra-State transmission system was considered for evacuation.



e) Neyveli TPS II Stage II: As per the PIB approval (Annexure-VI), full evacuation was planned through 400 kV ISTS and no intra-State transmission system was considered for evacuation.

f) NTECL Vallur TPS: As per the Minutes of 27th Standing Committee on Power System Planning in SR held on 03.03.2009 (Relevant extract is at Annexure-VII), interconnecting 400 kV D/Cline between Vallur TPS and North Chennai TPS II Projects was not identified as a part of the Evacuation System for NTECL Vallur TPS. It was mentioned under Evacuation system for North Chennai TPS II that as this line is also to be used for evacuation and reliability of Vallur TPS power, 50% of the transmission charges for this line would be pooled in the SR pool and paid to TNEB.

g) NPCIL Kudankulam NPP: As per the Minutes of 18th Standing Committee on Power System Planning in SR held on 05.03.2004 (Annexure- VIII), the 220 kV connectivity was planned for start-up power arrangement. 400kV Transmission System only had been identified as the Evacuation System for Kudankulam NPP.

h) NPCIL MAPS: To be treated as a special case as it is not falling under Regulation 13(11) of CERC Sharing Regulations 2020.

III. DELIBERATIONS IN THE MEETING:

1. SE(C), SRPC informed that in the first meeting of LTA Sub-Group, members sought to know that how the unallocated share of the stations is being considered for arriving at LTA quantum and the methodology followed in apportioning such quantum between ISTS and intra-STS in the specific cases where NLDC is giving exemption for the DICs availing power from IGSTPS Jajjhar, KBUNL, NTPC Simhadri St-I, NTPC Meja, RGPPL etc. He requested NLDC to apprise the Sub-Group in this regard.

2. NLDC informed that the LTA quantum exempted by CERC for respective DICs in the specific CERC Orders is being considered by NLDC.

3. SRPC requested NLDC to present the list of stations and the LTA quantum being exempted. However, NLDC stated that the details are not readily available. Further added that TANGEDCO/DICs may go through the specific CERC Orders to know the LTA quantum exempted by CERC.

Sub-Group expressed concern that the inputs are not made available by NLDC despite the requirement is mentioned in the Record Notes/Agenda of the Sub-Group meetings and repeated requests made by SRPC Secretariat through e-mails.

On a query, NLDC informed that NPCIL-MAPS is not in the list of 29 Generating Stations connected to both ISTS and intra-State transmission system that were referred to CTUIL.

NLDC was again requested to furnish the details of stations along with the exempted LTA quantum under various specific CERC Orders. NLDC agreed to furnish the same.

4. TANGEDCO stated that in the CERC Orders, CERC has given clear directions regarding how to deal the cases of the Generating Station connected to both ISTS and STU system. Based on the



CERC Orders, NLDC should consider/make applicable those CERC directions to the similar cases. CERC in the Statement of Reasons of Sharing Regulations 2020 and in the Explanatory Memorandum has clearly mentioned that since there is no provision in Sharing Regulations 2010 they have brought the provision 13(11) to deal with such cases. Hence, NLDC is required to implement the Regulations 13(11) of the Sharing Regulations 2020. In case of MAPS, it is evacuated fully through TANTRANSCO system, hence there is no question of billing for ISTS on Tamil Nadu. MAPS case is similar to the case of Simhadri STPS Stage I, hence the CERC Order in respect of Simhadri Stage I may be implied to MAPS case and LTA may be exempted for Tamil Nadu. TANGEDCO further informed that in the CERC Order dated 09.03.2018 in Petition No. 20/MP/2017, it was clearly mentioned about the Treatment of generic issue where generator is connected to both STU System & ISTS system and the same may be followed for the cases under Regulation 13(11).

5. SRPC stated that specific CERC Orders for a particular generating station may not be applied to other generating station though they may be falling under similar category. Those were the cases where concerned CGS which are connected only to STU system and CGS which are connected to both ISTS and STU systems had approached CERC and got the LTA exempted. But in the case of MAPS, there is no specific CERC Order to exempt the LTA quantum.

It was also pointed out that the treatment of generic issue mentioned in that Order referred by TANGEDCO pertained to the cases where LTA had been granted by CTU. Also the cases mentioned in the SoR & Explanatory Memorandum for Sharing Regulations 2020 seems relevant to the cases of LTA that is granted by CTU. But the main focus of the Sub-Group is generating stations where there is no LTA, and to arrive at the capacity connected to ISTS & intra-State transmission system.

6. SRPC requested members to share their views if there is difference of opinion on the agreed methodology in the first meeting of the Sub-Group for ascertaining the adequacy of intra-STU Network to evacuate their share from a CGS connected to both STU system & ISTS. SRPC elaborated the basis of methodology/ considering the intra-STU network planned and implemented at the time of commissioning of the concerned CGS as below:

ISTS is planned by the Standing Committee after extensive system studies keeping in view of the Transmission Planning Criteria.

The subsequent development of STU network from CGS are planned by the home state based on their requirement only.

The charges for the ISTS implemented based on the recommendations of the Standing Committee needs to be shared by the beneficiaries/DICs as per the criteria emphasized in the Sharing Regulations.

7. TANGEDCO stated that the Sharing Regulations have been changing from time to time as Sharing Regulations 2010 were based on the Usage of ISTS transmission assets (based on the PoC methodology) and now it has been changed to LTA based and it may undergo change again. Since different methodologies are being adopted to share the transmission charges



among DICs and billed accordingly, LTA quantum has also to be considered according to sharing methodology. It may be appropriate to consider the present Intra-State Transmission capacity connected and same to be exempted as per the Sharing Regulations 2020.

TANGEDCO pointed out that in the first LTA Sub-Group meeting, it was proposed to consider the cases of evacuation system as on 1.11.2020 as well as on the current date in addition to Evacuation System originally approved for studies. Hence, it may not be correct to determine LTA quantum from the studies by considering only the case of original approved transmission system.

8. SRPC stated that in the first meeting it was clearly noted that only case of originally approved evacuation system was discussed and agreed upon. However, for comparative purpose, the other cases of evacuation system as on 01.11.2020 & as on date may also be studied for ascertaining the adequacy of the intra-STS evacuation system. Then, the rationale for considering only the originally approved transmission system was also explained.

9. MS, SRPC informed that in the third CERC interaction meeting with RPCs, Technical Member, CERC also opined that the originally planned evacuation system only to be considered for LTA exemptions to the home state and subsequent additions of the transmission system / real time flow should not be considered for ascertaining/ to arrive at exempted LTA quantum.

10. APTRANSCO stated that they are agreeable to the methodology agreed in the first meeting of the Sub-Group.

11. TSTRANSCO informed that the proposed methodology is agreeable to them. SR has taken initiation to address the LTA issues and the recommendations of the Sub-Group would be put up to higher forums of SRPC for finalization. TSTRANSCO emphasized that NLDC needs to provide the clarification for arriving the exempted LTA quantum and their involvement is very much required in finalization of the methodology.

12. After deliberations, Sub-Group agreed in-principle with the methodology that had been proposed in the first meeting of LTA Sub-Group as follows:

a) The intra-STU network planned and implemented at the time of commissioning of the concerned Central Generating Station (CGS) only to be considered.

b) ISTS Network connected to CGS may be taken out of service and CGS may be left connected with intra-state transmission system (STU network) of home state. If the home state STU system is meeting the all the requirements as per the transmission planning criteria to evacuate their share, then that quantum may be considered for exemption in the computation of sharing of transmission charges.

c) Latest ATC/TTC All India Peak Base Case may be used for this purpose.

d) Ex-Bus Firm + Un-allocated quantum of the beneficiaries (i.e., 100% of CGS net capacity) to be considered to evaluate whether the home state STU system is capable of evacuating their share.



13. SRPC informed that as decided in the First Meeting of LTA Sub-Group, NTPC Kudgi STPS, Neyveli New Thermal Power Station (NNTPS), NTPC Simhadri STPS Stage I & UPCL had not been considered by the Sub-Group since LTA was granted by CTU/Specific CERC Orders.

14. PCKL requested to clarify whether the UPCL case falls under Regulation 13 (11) of Sharing Regulations 2020.

SRPC clarified that this Sub-Group had been constituted to formulate a methodology only for those Generating Stations falling under Regulation 13(11) where LTA has not been granted by CTU. But for UPCL, LTA had been granted by CTU and there are specific CERC Orders. PCKL may take up the issue appropriately.

PCKL informed that they would take up the UPCL case in the TCC meeting of SRPC for deliberation.

15. Generating Station wise deliberations/recommendations are as follows:

A. NPCIL MAPS, Kalpakkam:

a) Observations/Deliberation: i) The evacuation of MAPS is fully planned through Tamil Nadu 230 kV system. There is

no ISTS connected to MAPS. As such Regulation 13(11) of the Sharing Regulations 2020 cannot be applied.

ii) There may be cases similar to MAPS, where CERC had exempted LTA through specific Orders, but the same cannot be applied to MAPS.

b) Recommendation: In view of the above observations, Sub-Group is of the opinion that MAPS is a special case and methodology cannot be applied, hence MAPS case may be put up to TCC/SRPC.

B. NTPC Ramagundam STPS Stage I & II:

a) Observations/Deliberation:

i) As per the study based on the agreed methodology, TSTRANSCO system connected to RSTPS is capable of evacuating Telangana share from NTPC Ramagundam STPS Stage I &II.

ii) 400/220 kV ICTs and 400/132kV ICTs are owned by NTPC Ramagundam and the charges of the ICTs are included the capacity charges and shared by the beneficiaries of RSTPS.

iii) TSTRANSCO informed that in the year 2016, the failed 400/132 kV ICT had been replaced by TSTRANSCO with 400/220 kV ICT.

iv) PCKL pointed out that in case LTA is exempted for Telangana, then all the ICT charges should be borne by Telangana only.

v) CTUIL informed that ICTs are normally owned by Generating Stations and the ICTs are considered as ISGS points not the ISTS point. This is a general and standard



practice and is consistent with the similarly placed cases where LTA exemption had been given vide specific CERC Orders.

b) Recommendation: In line with the agreed methodology, LTA may be exempted for Telangana for the quantum of its share from Ramagundam STPS Stage-I & II.

C. NTPC Ramagundam STPS Stage III:


As per the Minutes of the 9th Standing Committee of Power System Planning in SR, RSTPS Stage III was planned to evacuate fully through the ISTS, hence it does not qualify for LTA exemption under Regulation 13(11).

b) Recommendation: In line with the agreed methodology, LTA exemption for Telangana may not be considered for Ramagundam STPS Stage III.

D. NLC TPS II Stage I:


As per the study based on the agreed methodology, TANTRANSCO system is capable of evacuating Tamil Nadu share from NLC TPS II Stage I.

b) Recommendation: In line with the agreed methodology, LTA may be exempted for Tamil Nadu for the quantum of its share from NLC TPS II Stage I.

E. NLC TPS II Stage II:


i) 400kV lines were identified for evacuation of power from NLC TPS II Stage II.

ii) ICT’s between NLC TPS II Stage I & Stage II are meant for exporting other beneficiaries’ share from Stage-I.

iii) CTU informed that 400 kV lines emanating from NLC TPS II Stage II are ISTS and both ends are ISTS points.

iv) TANGEDCO stated that the entire Tamil Nadu share from NLC TPS II Stage I & Stage II can be evacuated through their intra-state transmission system. Hence, requested to exclude TN share of Stage I and Stage II from LTA quantum.

v) It was observed that total share from both stages may be evacuated with the existing STU system but not with the original system planned.

vi) MS, SRPC informed that in the third interaction meeting with RPCs, Technical Member CERC has stressed the need to go for origin/planning of the transmission system and the history on what basis the transmission system had been planned. As



time passes, changes in network configurations/ flows may take place in the power system and the ISTS power may take the route of Intra-state transmission system or vice versa. In those situations, CERC has mentioned in the meeting that the respective states may approach CERC directly for claiming the tariff of the STU system. As per the present STU network, Tamil Nadu may be capable of drawing their share but original system planned needs to be considered for allowing LTA exemption under Regulation 13(11).

vii) After deliberations, the general consensus was that NLC TPS II Stage II does not qualify for LTA exemption since it was planned to be evacuated fully through the ISTS.

b) Recommendation:

In line with the agreed methodology, LTA exemption for Tamil Nadu may not be considered for its share from NLC TPS II Stage II.

F. NTECL Vallur TPS:


i) SRPC stated that as per the Minutes of 27thMeeting of Standing Committee of Power System Planning of SR, the interconnecting 400 kV D/C line between Vallur TPS and NCTPS II was not identified as a part of the evacuation system of NTECL Vallur TPS. It was, however, mentioned under Evacuation System planned for NCTPS II that since the D/C line is also used for evacuation and reliability of Vallur TPS, 50% of the transmission charges for this line would be pooled in the SR pool and paid to TNEB. Thus, the interconnecting D/C line had been recognized as deemed ISTS line by the standing committee (since the charges of the line is to be recovered through transmission charges from SR Pool).Further, the power flow on the D/C line depends on the generation levels at Vallur TPS and NCTPS TS II. Even if the line were to be considered as part of ATS for Vallur TPS, as per the agreed methodology, fulfilment of (N-1) criteria would not be met.

ii) TANGEDCO pointed out that as per the Standing Committee, the interconnecting line had been considered for both evacuation and reliability. In view of change in the scenario of CERC Sharing Regulations, it is requested to exclude the LTA quantum for Tamil Nadu instead of pooling the 50% of the transmission charges since the D/C line is being used for evacuation of power. As per the 26th Standing Committee, 50% of Vallur TPS- NCTPS II is the evacuation system for NTECL Vallur TPS and 50% of Vallur TPS- NCTPS II is the evacuation system for NCTPS II.(N-1) criteria shall be followed for planning purposes but for Commercial aspects, (N-1) criteria should not be a condition for arriving at the correct LTA quantum. The same had been dealt by the Hon’ble Commission in the cases of LTA exemption in the Order dated 04.05.2018 in Petition No. 126/MP/2017 and Order dated 9.3.2018 in Petition No.20/MP/2017.



iii) CTUIL stated that 400 kV Vallur TPS - NCTPS II D/c line had been approved as a part of ATS for North Chennai TPS-II. The deliberation in the 6th Standing Committee was an intermediate discussion and was not concluded. However, the same was concluded in the 27th Standing Committee. As per the 27th Standing Committee, this line is placed under the ATS of NCTPS Stage II. Moreover, Tamil Nadu only had requested the Standing Committee for the inter-connecting D/C line between two Generating Stations mainly for reliability. Installed capacity of NTECL Vallur TPS is 1500 MW and the installed capacity of NCTPS St-II is 1200MW, and under normal operating conditions, this line would be mostly floating and drawal through the line may not happen. (N-1) criteria as per the transmission planning criteria cannot be done away with. Even in the revised planning criteria, (N-1) criterion has been waived off only for immediate evacuation of RE power. Nowhere else this criteria should be violated.

iv) APTRANSCO opined that (N-1) contingency criteria as per the Transmission planning criteria shall always be adhered to without linking with any commercial benefits.

v) As per the agreed methodology, since NTECL Vallur TPS was planned to be evacuate fully through the ISTS, it does not qualify for LTA exemption. However there was no consensus.

b) Recommendation:

In view of the divergence of views from the members in respect of planned evacuation system, there is no consensus arrived in the case of NTECL Vallur TPS and hence Sub-Group concluded that the NTECL Vallur TPS case may be put up to TCC/SRPC.

G. NPCIL KKNPP:


As per the Minutes of 18thMeeting of Standing Committee on Power System Planning of SR, KKNPP was planned to evacuate fully through ISTS and the intra-STU network was basically meant for start-up power arrangement, hence it does not qualify for LTA exemption. TANGEDCO agreed with the same.

b) Recommendation:

In line with the agreed methodology, LTA exemption for Tamil Nadu may not be considered for KKNPP.

H. NPCIL Kaiga Stage-I & Stage-II


i) As per the Minutes of the 16thMeeting of Standing Committee on Power System Planning in SR, 400 kV ISTS were planned for evacuation of both the stages and no intra-State transmission system was considered for evacuation.



ii) PCKL informed that they had requested KPTCL to carry out the studies and present in the Sub-Group Meeting. However, KPTCL did not participate in the meeting due to state holiday and requested to provide opportunity to present their case in the TCC meeting.

iii) SRPC pointed out that in the Joint study meeting of the Sub-Group, PCKL had requested to allow presenting the study results of their cases in the 2nd Sub-Group meeting. It was agreed for that despite Kaiga GS being not qualified for LTA exemption as per the agreed methodology.

iv) CTUIL informed that as per the proposed Sharavathy Pumped storage scheme, KPTCL has planned to dismantle Talaguppa and Shimoga lines emanating from Shravathy and utilize the RoW for its evacuation scheme. With this arrangement, generation at Kadra and Kodasalli may be evacuated through the ISTS system.

b) Recommendation:

In line with the agreed methodology, LTA exemption for Karnataka may not be considered for Kaiga GS Stage- I & Stage-II.

16. KSEBL appreciated the efforts taken by SRPC Secretariat, CTUIL, TANGEDCO and other entities for providing a platform for discussion and for resolution of the issues in respect of Sharing Regulations 2020. KSEBL requested to put forth the decisions/ conclusions to the next TCC meeting of SRPC.

IV. CONSOLIDATED CONCLUSIONS/RECOMMENDATIONS OF THE SUB-GROUP a) Following methodology was agreed in principle by the Sub-Group for ascertaining the

adequacy of intra-STU Network to evacuate their share from a GS connected to both STU system & ISTS:

i) The intra-STU network planned and implemented at the time of commissioning of the concerned Central Generating Station (CGS) only to be considered.

ii) ISTS Network connected to CGS may be taken out of service and CGS may be left connected with intra-state transmission system (STU network) of home state. If the home state STU system is meeting the all the criteria as per the transmission planning criteria to evacuate their share, then that quantum may be considered for exemption in the computation of sharing of transmission charges.

iii) Latest ATC/TTC All India Peak Base Case may be used for this purpose.

iv) Ex-Bus Firm + Un-allocated quantum of the beneficiaries (i.e., 100% of CGS net capacity) to be considered to evaluate whether the home state STU system is capable of evacuating their share.

However, TANGEDCO has expressed the concern on considering only the originally approved transmission system and opined that it may be appropriate to consider the present Intra-State Transmission system connected to the Generating Station for evaluation of the capacity to be evacuated through Intra-State Transmission system for LTA exemption.



b) Following Generating Stations of SR connected to both ISTS and intra-State Transmission System have been considered and concluded as below:

SN Generating Station Observation Conclusion/Recommendation

1. NTPC Kudgi STPS

LTA was granted by CTU

These Generating Stations have not been considered by

the Sub-Group for ascertaining the adequacy of intra-STU Network to evacuate their

share from GS.

2 Neyveli New Thermal Power Station (NNTPS)

LTA was granted by CTU

3 NTPC Simhadri STPS Stage I

CERC vide Order 30.03.2017 in Petition No. 291/MP/2015 has exempted LTA.

4 UPCL LTA was granted by CTU

5 NTPC Ramagundam STPS Stage I & II

In line with the agreed methodology, TSTRANSCO system is capable of evacuating Telangana share.

LTA may be exempted for Telangana for the quantum of its share from Ramagundam STPS Stage-I & II.

6 NTPC Ramagundam STPS Stage III

RSTPS Stage III was planned to evacuate fully through the ISTS.

LTA exemption may not be considered.

7 NLC TPS II Stage I In line with the agreed methodology, TANTRANSCO system is capable of evacuating Tamil Nadu share.

LTA may be exempted for Tamil Nadu for the quantum of its share from NLC TPS II Stage I.

8 NLC TPS II Stage II 400kV lines were identified for evacuation of power from NLC TPS II Stage II.

However, TANGEDCO submitted that the entire Tamil Nadu share from NLC TPS II Stage I & Stage II can be evacuated through their intra-state transmission system.


9 NTECL, Vallur TPS There was divergence of views as below:

TANGEDCO: The interconnecting line (400 kV Vallur TPS –

Case may be considered by TCC/SRPC.



NCTPS St II D/c line) was considered for evacuation of power from NTECL as well as the reliability.

CTUIL: The interconnecting line was planned as the ATS of NCTPS St-II and not in the evacuation scheme of NTECL Vallur TPS.

10 NPCIL, KKNPP KKNPP was planned to be evacuated fully through the ISTS.


11 NPCIL, Kaiga GS Stage-I & II

400 kV ISTS were planned for evacuation of both the stages and no intra-State transmission system was considered for evacuation.

LTA exemption for Karnataka may not be considered.

c) NPCIL MAPS Kalpakkam: Case may be considered by TCC/SRPC.

V. CONCLUSION

MS, SRPC thanked the members and participants for their active participation in the meeting. The outcome of the Sub-Group would be put up to TCC/SRPC in the 39th TCC/SRPC Meetings scheduled on 03.12.2021/06.12.2021.

*****


Annexure-I

Date: 22.11.2021 Through VC Time: 11:00 hrs

SL. NO Name of the Participant Designation Organisation Email ID1 Smt. P Jyostna Rani Executive Engineer/Regulatory Affairs APTRANSCO [email protected]

2 P C Kondalarao Executive Engineer/Sys Studies/APSLDC APSLDC [email protected]

3 A V L K J Sharma Dy Executive Engineer APTRANSCO [email protected]

4 Smt. Savitri JD PCKL [email protected]

5 Smt. Rekha R DD PCKL [email protected]

6 Smt. Gertrude.K.G AEE KSEBL [email protected]

7 Shri. R Krishna Kumar AEE KSEBL [email protected]

8 Ms. R. Ramalakshmi SE TANGEDCO [email protected].

9 Shri M.Sudarsan SE TANGEDCO [email protected].

10 Dr.R.Kathiravan EE TANGEDCO [email protected]

11 Shri. P Suresh Babu SE TSTRANSCO [email protected]

12 Ms. V.Yashodhara Rani SE TSTRANSCO [email protected]

13 Shri Anil Kumar Meena Sr. DGM CTUIL [email protected]

14 Shri Venkatesh Gorli CTUIL

15 Shri S Tushanth Siddarth CTUIL

16 Shri Sanny Machal Manager NLDC [email protected]

17 Shri S P Kumar CGM SRLDC [email protected]

18 Shri. Ravi Shankar C Chief Manager SRLDC [email protected]

19 Shri. K B V Ramkumar Manager SRLDC [email protected]

20 Shri Naresh Bhandari Member Secretary SRPC [email protected]

21 Shri NRLK Prasad Superintending Engineer SRPC [email protected]

22 Shri Meka Ramakrishna Superintending Engineer SRPC [email protected]

23 Shri K P Madhu Superintending Engineer SRPC [email protected]

24 Ms. Anusha Das J Executive Engineer SRPC [email protected]

Second meeting of LTA Sub-group held on 22.11.2021


mailto:[email protected]















E-mail

भारतसरकार

कें द्रीयविद्यतुप्राविकरण

दविणिेत्रीयविद्यतुसविवत

29, रेसकोसस क्रास रोड

बेंगलूर - 560 009

Government of India


Southern Regional Power Committee

29, Race Course Cross Road

Bengaluru - 560 009

Web site: www.srpc.kar.nic.in Email: [email protected] Phone: 080-22287205

सं/No. SRPC/SE1/2021-22/ दिन ंक /Date 29th

October 2021

To

All Sub-Group Members as per the Mailing List

Sub: First Meeting of the Sub-Group to formulate a philosophy on LTAquantum of the

generating stations connected to both ISTS and intra-State transmission system -

reg.

Madam/Sir,

Record Notes of the First Meeting of LTA-Sub Group to formulate a philosophy on LTA quantum of the

generating stations connected to both ISTS and intra-State transmission system held on 28.10.2021 is

herewith enclosed.

Encl: as above

Yours faithfully,

(मेकारामकृष्ण/ MEKA RAMAKRISHNA)

अधीक्षणअभियन्ता(वा)/Superintending Engineer (C)

Mailing List:

1. Shri. P Ch Kondala Rao, EE, APTRANSCO([email protected])

2. Shri.A V L K J Sharma, Dy.EE, APTRANSCO([email protected])

3. Smt. P Jyostna Rani, EE, APTRANSCO ([email protected])

4. KPTCL([email protected])

5. Smt. Savitri, JD,PCKL([email protected])

6. Smt. Rekha R, DD, PCKL ([email protected])

7. Smt. Latha S.V, AEE, KSEBL ([email protected])

8. Shri. R Krishna Kumar, AEE, KSEBL([email protected])

9. Shri. T. Subbarayan, SE, TANTRANSCO([email protected])

10. Ms. R. Ramalakshmi, SE, TANGEDCO ([email protected])

11. Shri. M.Sudarsan, SE(SS), TANTRANSCO([email protected])

12. Shri. P Suresh Babu, SE, TSTRANSCO ([email protected])

13. Ms. V.Yashodhara Rani, SE, TSTRANSCO ([email protected])

14. Puducherry ED ([email protected])

15. Shri. Anil Kumar Meena, Sr. DGM, CTUIL ([email protected])

16. Shri. V Srinivas, Sr. DGM, CTUIL([email protected])

17. Shri. Ravi Shankar C, CM, SRLDC([email protected])

18. Shri. KBV Ramkumar, Manager, SRLDC ([email protected])

19. Shri. Sanny Machal, Manager, NLDC([email protected])

Annexure II - Page 1 of 34Annexure CS.1 (Page 16 of 144)













Record Notes of the First Meeting of LTA Sub-Group held on 28.10.2021 1/8

SOUTHERN REGIONAL POWER COMMITTEE

Bengaluru

Record Notes of the First Meeting of LTA Sub-Group of Southern Region

(held on 28th

October 2021 through VC)

1. INTRODUCTION:

1.1 First meeting of LTA Sub-Group was held on 28th

October 2021 through Video Conferencing (VC).

The list of participants is at Annexure-I. The representative from NLDC has not attended the

meeting.

1.2 Superintending Engineer (Commercial), SRPC extended a hearty welcome to all the Sub-Group

Members to the first meeting of the LTA Sub-Group. He briefed the Sub-Group members about

the objectives of the Sub-Group.

1.3 Member Secretary (I/c), SRPC welcomed all the participants to the first Sub-Group meeting. He

stated that as decided in the Special TCC meeting held on 18.10.2021 (Minutes issued vide SRPC

letter dated 21.10.2021 are available in SRPC website), a Sub-Group (LTA-SubGroup) comprising

Members from CTUIL, NLDC, SRLDC and SLDCs of Southern Region (SR) had been constituted vide

SRPC letter 25.10.2021 with the objective of formulating an Objective Methodology/ General

Philosophy to be adopted for determining Long Term Access and Medium Term Open Access

corresponding to capacity connected to ISTS in case of Generating Stations connected to both

ISTS and intra-State transmission system. In this regard, relevant details like the list of Central

Generating Stations (CGS) in the Southern Region, their details of allocation/deemed LTA and

CGS having connectivity with STU & ISTS were also circulated along with the Meeting Notice

(Annexure-II). In view of the scheduled 3rd

interaction meeting of Hon’ble CERC with RPCs on

17.11.2021, he hoped for a definite outcome from the subgroup by that time so that the finalized

methodology may be apprised to the Commission. He emphasized that during deliberations, two

things may be given proper attention – (i) the quantum of LTA plus MTOA to be considered for

apportioning between ISTS and intra-STS, and (ii) the reference time period with reference to

which the intra-STS evacuation system for the concerned CGS, and rest of the Network needed

to be considered. With respect to the former, suitable treatment may need to be given for

factoring in un-allocated share and auxiliary consumption appropriately. The second one is also

equally important since the intra-STS evacuation Network for the concerned CGS and rest of the

Network keep changing with time. In this connection, the originally planned/ approved

evacuation system/ associated transmission system, along with conditions, if any, for the

concerned CGS may also need to be factored in appropriately. He stated that the probable dates

of said reference period could be one of (a) time period when evacuation system was planned

for respective CGS, or (b) Present time, or (iii) 01.11.2020 (when 2020 Sharing Regulations came

into force).

2. BACKGROUND:

2.1 In the Special Meeting of TCC held on 18.10.2021, it was decided that a Sub-Group would be

formed under SRPC Secretariat with representatives from CTUIL, NLDC, SRLDC and SLDCs of SR to



formulate on Objective Methodology/ General Philosophy to be adopted for determining Long

Term Access and Medium Term Open Access corresponding to capacity connected to ISTS in case

of Generating Stations connected to both ISTS and intra-State transmission system and submit its

recommendation to TCC within one month.

2.2 Accordingly, a Sub-Group (LTA-Sub Group) comprising the following Members from CTUIL, NLDC,

SRLDC and SLDCs/STUs of Southern Region has been constituted vide SRPC letter no: SRPC/SE-

I/2021-22 dated 25.10.2021:

1) Shri. P Ch Kondala Rao, EE, APTRANSCO

2) Shri.A V L K J Sharma, Dy.EE, APTRANSCO

3) Ms P Jyostna Rani, EE, APTRANSCO

4) Ms Savitri, JD,PCKL

5) Ms Rekha R, DD, PCKL

6) Ms Latha S.V, AEE, KSEBL

7) Shri R Krishna Kumar, AEE, KSEBL

8) Shri T. Subbarayan, SE (LD&GO), TANTRANSCO

9) Ms. R. Ramalakshmi, SE (CERC), TANGEDCO

10) Shri M.Sudarsan, SE(SS), TANTRANSCO

11) Shri P Suresh Babu, SE, TSTRANSCO

12) Ms V.Yashodhara Rani, SE, TSTRANSCO

13) Shri Anil Kumar Meena, Sr. DGM, CTUIL

14) Shri V Srinivas, Sr. DGM, CTUIL

15) Shri Ravi Shankar C, CM, SRLDC

16) Shri KBV Ramkumar, Manager, SRLDC

17) Shri Sanny Machal, Manager, NLDC

3. DELIBERATIONS:

3.1 SE (C), SRPC stated that the main objective is to formulate a methodology for determining the

quantum of LTA corresponding to the capacity connected to ISTS from the MoP share

allocation of the State for Central Generating Stations (CGS) connected to both ISTS and Intra-

State Transmission System. It is also required to identify CGS of SR which are eligible to be

considered under the Regulation 13 (11) of CERC Sharing Regulations 2020.

He observed that the CGS for which LTA had been granted by CTU need not be considered by

the Sub-Group. As such, NTPC Kudgi STPS, Neyveli New Thermal Power Station (NNTPS), which

has been granted LTA by the CTU as per the applicable CERC Regulations, need not be

considered. Simhadri STPS (Stage-I) & Simhadri (Stage-II) also need not be considered for

discussion as there are specific CERC Orders. UPCL station which is an Inter State Generating

Station (ISGS) has also granted LTA by CTUIL, hence that also need not be considered by the

Sub-Group.

3.2 CTUIL pointed out that it has been deliberated in one of the Standing Committee meetings that

Simhadri Stage-I is evacuated through APTRANSCO Network and NTPC Simhadri STPS Stage-II is

completely evacuated through ISTS network. The interconnector between NTPC Simhadri STPS

Stage-I and Stage-II has been provided for reliability/ contingency purposes. In case of UPCL,



the matter is sub judice as there is a petition in APTEL and the LTA was granted by CTUIL

through LTA route.

3.3 PCKL requested that UPCL may also be deliberated by the Sub-Group. On this, it was agreed

that after finalization of the methodology, Sub-Group may decide whether the finalized

methodology may be adopted to UPCL or not.

3.4 In this connection, MS I/c, SRPC enquired from TANGEDCO whether the present issue of LTA

reduction had been mentioned in the writ petition filed by TANGEDCO before the Hon’ble High

Court of Madras, to which TANGEDCO replied in the negative.

3.5 The Sub-Group agreed that NTPC-Kudgi STPS, Neyveli New Thermal Power Station (NNTPS)

Simhadri STPS (Stage-I), Simhadri STPS (Stage-II), and UPCL would not be considered since they

do not qualify for adopting Regulation 13 (11) of CERC Sharing Regulations 2020 for LTA

bifurcation.

3.6 CTUIL stated that Sub-Group while finalizing the methodology for bifurcation of LTA between

ISTS and STU, must consider the time & the circumstances under which the evacuation system

had been approved. Subsequent additions of transmission lines for evacuation of their share by

home state may not be considered since it may benefit to the home state and other

beneficiaries would get burdened.

3.7 TSTRANSCO requested that the associated transmission system during the commissioning of

the CGS needed to be considered for the purpose of finalizing the methodology.

3.8 TANGEDCO informed that they have been paying the charges that they are not supposed to be

paid for long time and are not asking to share the burden of TANGEDCO by other beneficiaries.

It is over billed for wrong inclusion of LTA. Transmission scheme approval for CGS during the

commissioning and sharing of transmission charges are different issues since over the time

methodology of sharing of transmission charges has been changing (Postage Stamp Method

before 2010, Point of Connectivity method before 2020 that is mainly based on the usage of

the transmission system, and then LTA based sharing as per ISTS Sharing Regulations, 2020). In

CERC Sharing Regulations 2020, it is clearly stated that the capacity connected with ISTS shall

only be used for sharing of the transmission charges whereas in CERC Sharing Regulations

2010, there was no provision for the same. CERC also mentioned about the capacity connected

with ISTS for sharing of the ISTS transmission charges in the explanatory memorandum and the

statement of Reasons in respect of 2020 Sharing Regulations. TANGEDCO requested to

implement the Regulations positively.

3.9 KSEBL stated that the Sub-Group is over stepping into the jurisdiction of CERC and not the

authority to interpret the Regulation. There are different interpretations of Regulation 13(11).

In KSEBL point of view, the method of treating the allocation of CGS as deemed LTA for

transmission charge calculations has been in force since long time. CERC has never intended to

change this method through the Sharing Regulations 2020. This is also clear form 6.1 of NLDC

Procedure in compliance of 2020 Sharing Regulations. CERC should be approached for

interpretation of the Regulation 13(11).

3.10 MS I/c, SRPC pointed out that the Sub-Group had been constituted based on the

recommendation of TCC of SRPC in their special meeting held on 18.10.2021 after arriving the



consensus. The limited mandate of the Sub-Group is to discuss and finalize an objective

methodology/ general philosophy in this regard and the same would be put up to TCC forum of

SRPC for further action. If TCC agrees for the methodology, the same may be taken up with

CERC by CTU/ NLDC for approval.

3.11 SE (C), SRPC observed that NPCIL MAPS is evacuated through 4 No.s of 230 kV lines of

TANTRANSCO (STU system) and no ISTS connectivity. He requested the views of Sub-Group for

consideration of LTA reduction to Tamil Nadu.

3.12 CTUIL informed that the implementation of transmission system for MAPS had been done long

back and CTUIL did not have any supporting documents how the transmission scheme had

been planned and implemented. The criteria followed in this regard was also unknown.

However, it is clear that the transmission system of TANTRANSCO is being used for evacuation

of MAPS. CTUIL enquired how the transmission charges would be shared by other

beneficiaries, when MAPS is considered as state embedded system. The issues becomes

significant in case TANTRANSCO files a petition at a later date for recovering the transmission

charges of their system, and needs to be discussed/ clarified.

3.13 TANGEDCO informed that they were not raising the issue of sharing of transmission charges for

evacuation lines of MAPS by other beneficiaries and their only submission is to exclude the

quantum of power allocated from MAPS from total LTA of Tamil Nadu being considered for

sharing of transmission charges as per the CERC Sharing Regulations 2020.

3.14 TSTRANSCO enquired what mechanism to be adopted for finalizing the LTA quantum in case of

CGS. It should be finalized first and subsequently the matter of bifurcation of LTA may be

discussed / finalized. TSTRANSCO also enquired about the impact on other beneficiaries when

the LTA quantum for Tamil Nadu is reduced in case of MAPS. On this, it was noted that there

would be impact on all other DICs across the nation based on the ratio of LTAs of individual

DICs.

3.15 CTUIL informed that there was no mechanism for considering/ converting the CGS allocation as

deemed LTA/proposed LTA. There is 15% unallocated share for CGS which keeps changing. The

same has been categorically informed to NLDC. Further, once the LTA is granted, the same shall

have to be continued till relinquishment. There is no procedure/provision for conversion of

CGS allocation to LTA as on date. That is the difficulty is being faced by CTU and NLDC.

3.16 KSEBL stated that it would be precedence for other states in future and there would be

commercial impact on the DICs nationwide.

3.17 On a query from TSTRANSCO, whether the MAPS evacuation lines are treated as deemed ISTS

line or the transmission charges are exclusively borne by Tamil Nadu, TANGEDCO replied that

the transmission charges are not being recovered through CERC sharing Regulations presently.

3.18 CTUIL informed that NLDC has referred to them a total no. of 29 generating stations connected

to both STU and ISTS which includes NLC II Stage -1 & 2, NTECL Vallur and KKNPP of SR. After

holding deliberations internally and considering various orders of the Commission, CTU had

referred back to NLDC stating that they were unable to sought details/ information in the

absence of any procedure for conversion of CGS allocation to LTA. If SRPC forum comes out



with a suitable recommendation giving rational formulae in this regard, CTU would surely

consider the same for implementation.

As regards to the methodology to be adopted for ascertaining the adequacy of intra-STU

Network to evacuate their share from a CGS, CTUIL suggested that ISTS Network connected to

CGS may be taken out of service, and CGS may be left connected with intra-STS system of the

home state. If the home state STU system is meeting the all the criteria as per the transmission

planning criteria to evacuate their share, then that quantum may be considered for exemption

in the computation of sharing of transmission charges. In this regard, the studies may be done

considering the intra-STU network planned and implemented at the time of commissioning of

the concerned CGS.

CTUIL stated that studies could be carried out by NLDC/ SRLDC in order to ascertain whether

the intra-STS network is sufficient to evacuate their respective share through their available

system as per the above proposal.

3.19 In this regard, TANGEDCO sought to know how the unallocated share of the stations is being

considered for arriving at LTA quantum in the specific cases where NLDC is giving exemptions

for the DICs availing power from IGSTPS Jajjhar, KBUNL, NTPC Simhadri St-I, NTPC Meja, RGPPL

etc. On the similar lines, the unallocated share of the TANGEDCO to be considered. It was

noted that NLDC has such information on the above cases referred to by TANGEDCO.

3.20 Sub-Group expressed concern regarding the non-participation of NLDC in the meeting.

3.21 CTUIL informed that the Regulation 13(11) had been inserted on the request of NLDC/POSOCO.

CTUIL was opposing this provision in view of no rational formula for conversion of CGS

allocation into LTA/MTOA. There is an issue of 15% unallocated quota which is a huge quantum

throughout the nation and the same needs to be converted into LTA on monthly basis. Hence

the views of NLDC/ RLDC are must in this respect for finalizing the methodology by Sub-Group.

CTUIL requested that NLDC/ SRLDC to take the lead in studies/ analysis and CTUIL & SRPC can

be a part.

3.22 MS I/c, SRPC pointed out that being the implementing Agency of CERC ISTS Sharing Regulations

2020, the views of NLDC are very much required in order to formulate a suitable methodology.

He requested SRLDC to consult the nominated officer from NLDC and ensure participation of

NLDC in the next Sub-Group meeting onwards.

3.23 After deliberations on the proposal of CTUIL, the following was agreed w.r.t. the studies to

be done for each CGS connected to both ISTS & Intra-STS:

a) The Firm + Un-allocated quantum, (i.e., 100% of CGS capacity) discounted by normative auxiliary

consumption of the CGS shall be considered and apportioned among various beneficiaries in their

ratio of Firm allocation. These details are given at Annexure-III for kind reference.

b) W.r.t. the Network to be considered for Intra-STS evacuation System & Rest of the System, it was

noted that the following possibilities would emerge:

SN Rest of the System Intra-STS Evacuation System

1 Latest ATC/TTC All India Peak Base Case as

on Date

i. Evacuation System originally

approved



ii. Evacuation System as on Date

2 ATC/TTC All India Peak Base Case as on

01.11.2020


approved

ii. Evacuation System as on

01.11.2020

3 The surrounding area Network (only)

present at the time of approval of originally

planned intra-STS evacuation system


approved

W.r.t. Rest of the System at ‘1’ & ‘2’, it was opined that that since effect of Rest of the system on

intra-STS evacuation system may not vary significantly if the time-frame considered is less, it was

decided to consider Latest ATC/ TTC All India Peak Basecase in preference to that as on 01.11.2020

for studies. W.r.t. ‘3’, it was opined that data availability could be an issue; however, if the same is available, that also can be considered for studies. Accordingly, it was decided to consider the Cases

of (1-i), (1-ii), and (3-i) for each CGS for performing studies. [It may be noted that in the meeting

only Case (1-i) was discussed; however, for comparative purpose, Case (1-ii) can be studied. Further,

if the old data available, Case (3-i) may also be considered for ascertaining the adequacy of the

intra-STS evacuation system]

c) For the Cases (1-i) & (1-ii) for each Generating Station, the studies shall be performed as follows:

i. All the ISTS lines connected to the CGS shall be taken out of service and the CGS

under consideration may be left connected only with the intra-STS evacuation system.

ii. Consider the dispatch (generation) from the CGS under consideration as the home

state share as given/ arrived at (a) [refer Annexure-III].

iii. Scale down the loads of the beneficiaries (other than the home state) by appropriate

quantum (to account for losses) corresponding to their respective share in the CGS as

given/ arrived at (a) [refer Annexure-III].

iv. Solve the full network for convergence. Now this shall be the New Basecase for

further determining (N-1) criterion fulfillment.

v. Now check for (N-1) criteria fulfillment. [In this regard, it was noted that since the CGS

under consideration is essentially radially injecting into the rest of the Network,

fulfillment of the (N-1) criterion in the immediate intra-STS evacuation network is

sufficient to prove the adequacy of the intra-STS evacuation system in evacuating

their share from the CGS under consideration].

vi. In case, the (N-1) criterion is not fulfilled, Steps (iv) & (v) above shall be repeated by

reducing considered CGS generation by suitable quantum in each iteration.

vii. Finally, the quantum of generation from the CGS under consideration at which (N-1)

criterion gets fulfilled shall be considered as the quantum which the intra-STS

evacuation of the state can safely evacuate from the CGS under consideration; hence

the same can be considered for exemption in the LTA plus MTOA share of the home

state.

d) For the Case (3-i) for each Generating Station, there may not be required to conduct any formal

study. By carefully examining the Surrounding area Network details together with the intra-STS

evacuation system (but after excluding ISTS evacuation system), the adequacy of the intra-STS

evacuation system to evacuate home state’s share from the CGS under consideration may be



checked. (This should be possible in view of the lesser no. of network elements present at that

time).

3.24 For conducting above studies, the latest All-India Peak Basecase given by SRLDC is given at

Annexure-IV.

3.25 Even though it was agreed to jointly conduct the above studies by NLDC, SRLDC, CTUIL, SRPC

and States on 02.11.2021 (Tuesday), it is strongly recommended that the Utilities as indicated

below shall come to the meeting by conducting the studies, and present the same in the

meeting.

The CGS to be considered for studies are given under:

Name of the CGS considered

for conducting Study

Name of the Utilities who

are recommended to pre-

conduct the Studies and

present the same in the

02.11.2021 meeting

Remarks

NPCIL, MAPS, Kalpakkam TN-SLDC/TANTRANSCO,

CTUIL, SRLDC/ NLDC

No study is required since it is a

clear-cut case for exemption.

NLC TPS II Stage I TN-SLDC/TANTRANSCO,

CTUIL, SRLDC/ NLDC

NLC TPS II Stage II TN-SLDC/TANTRANSCO,

CTUIL, SRLDC/ NLDC

NTECL, Vallur TPS TN-SLDC/TANTRANSCO,

CTUIL, SRLDC/ NLDC

NPCIL, KKNPP Unit-I TN-SLDC/TANTRANSCO,

CTUIL, SRLDC/ NLDC

NPCIL, KKNPP Unit-II TN-SLDC/TANTRANSCO,

CTUIL, SRLDC/ NLDC

NTPC Ramagundam STPS

Stage I & II

TS-SLDC/TSTRANSCO,

CTUIL, SRLDC/ NLDC

CTU/ TS-SLDC/ TSTRANSCO may

provide the originally approved

evacuation system. However, in the

absence of the same, the network

modifications done in the intra-STS

evacuation system in the last 20- 25

years may be ignored.

NTPC Ramagundam STPS

Stage III

TS-SLDC/TSTRANSCO,

CTUIL, SRLDC/ NLDC

CTU/ TS-SLDC/ TSTRANSCO may

provide the originally approved

evacuation system.

NPCIL, Kaiga GS Stage-I KA-SLDC/KPTCL, CTUIL,

SRLDC/ NLDC

CTU/ KA-SLDC/ KPTCL may provide

the originally approved evacuation

system. However, in the absence of

the same, the network






NPCIL, Kaiga GS Stage-II KA-SLDC/KPTCL, CTUIL,

SRLDC/ NLDC

CTU/ KA-SLDC/ KPTCL may provide

the originally approved evacuation

system. However, in the absence of

the same, the network




3.26 In the 02.11.2021 meeting, the joint Studies, if already conducted, would be evaluated for their

orderliness. If not, they would be conducted during the meeting day on 02.11.2021, in which

case the onus of providing all requisite details lies with concerned State-SLDC/ TRANSCO. It was

also agreed that that the Results of the Studies so conducted on 02.11.2021, after verifying

their orderliness, would be circulated to all Sub-Group Members, who then can hold second

meeting on a suitable date to decide the further course of action.

4. CONCLUSION:

MS (I/c), SRPC thanked the members and participants in the meeting for their active participation.

He requested all concerned Utilities to come fully prepared for the Joint Study Meeting on

02.11.2021.

*****


Annexure-I


SL. NO Name of the Participant Designation Organisation Email ID

1 Smt. P Jyostna Rani Executive Engineer/Regulatory Affairs APTRANSCO [email protected]


3 A V L K J Sharma Dy Executive Engineer APTRANSCO [email protected]



6 Smt. Latha S.V AEE KSEBL [email protected]


8 Shri. T. Subbarayan SE TANTRANSCO [email protected]







15 Shri V Srinivas Sr GM CTUIL


17 Shri Goodelli Madhukar DGM SRLDC [email protected]

18 Shri. Ravi Shankar C Chief Manager SRLDC [email protected]

19 Shri. K B V Ramkumar Manager SRLDC [email protected]

20 Shri NRLK Prasad Member Secretary (I/C) SRPC [email protected]




First meeting of LTA Sub-group held on 28.10.2021


















Annexure-II

Background:

In the Special Meeting of TCC held on 18.10.2021, it was decided that a Sub-Group

would be formed under SRPC Secretariat with representatives from CTUIL, NLDC, SRLDC

and SLDCs of SR to formulate an Objective Methodology/ General Philosophy to be

adopted for determining Long Term Access and Medium Term Open Access

corresponding to capacity connected to ISTS in case of Generating Stations connected to

both ISTS and intra-State transmission system and submit its recommendations to TCC

within one month.

Accordingly, a Sub-Group has been formed with the representatives (Technical &

Commercial) from APTRANSCO, KPTCL/PCKL, KSEBL, TANTRANSCO, TANGEDCO,

TSTRANSCO, Puducherry ED, CTUIL, NLDC & SRLDC. The details of Members are at

Annexure.

Information to the Members of the Sub-Group:

i. Regulation 13 (11) of CERC Sharing Regulations, 2020 which came into force w.e.f.

01.11.2020 stipulate as follows:

“Where a generating station is connected to both ISTS and intra-State

transmission system, only ISTS charges and losses shall be applicable on the

quantum of Long Term Access and Medium Term Open Access corresponding to

capacity connected to ISTS.”

ii. Central generating Stations(CGS) in the Southern Region:

1. NTPC RSTPS Stage I&II

2. NTPC RSTPS Stage III

3. NTPC Talcher STPS Stage II

4. NTPC Simhadri STPS Stage I

5. NTPC Simhadri STPS Stage II

6. NTPC Kudgi STPS Stage I

7. NTECL Vallur STPS

8. NLC TS II Stage I

9. NLC TS II Stage-II

10. NLC StageI Exp.

11. NLC StageII Exp.

12. Neyveli New Thermal Power Station(NNTPS)

13. NTPL

14. NPCIL, MAPS, Kalpakkam

15. NPCIL,Kaiga GS Stage-I

16. NPCIL,Kaiga GS Stage-II

17. NPCIL,KKNPP UNIT 1



iii. LTA granted by CTU for CGS:

1. NTPC Kudgi STPS Stage I -2250 MW

2. NNTPP -314.79 MW

iv. Special Case (CGS):

CERC vide Order dated 30.03.2017 in Petition No. 291/MP/2015 excluded the ISTS

transmission charges for Andhra Pradesh for drawal of its share from Simhadri STPS

Stage-I.

v. CGS considered under deemed LTA (LTA not granted by CTU):

1. NTPC RSTPS Stage I&II:

a) Installed Capacity(IC)= 2100 MW

b) Auxiliary Consumption=7.04%

c) Ex Bus Capacity/LTA for the station= 1952.16 MW

d) MoPAllocation of Power to the Entities:

Entity Allocation (%)

Andhra Pradesh 13.71

Karnataka 22.96

Kerala 11.67

Tamil Nadu 25.08

Telangana 17.08

Puducherry 4.70

Goa 4.76

HVDC-Gazuwaka 0.05

e) Monthly LTA to the DICs in MW =

(Allocation % of the DIC x Ex-Bus cap. of CGS)+ URS adjustment (MW) in

respective month

2. NTPC RSTPS Stage III

a) Installed Capacity(IC)= 500 MW


c) Ex Bus Capacity/LTA for the station= 468.75 MW

d) MoP Allocation of Power to the Entities:



Karnataka 24.06

Kerala 12.20

Tamil Nadu 26.35

Telangana 17.97

Puducherry 4.96



respective month


3. NTPC Talcher STPS Stage II

a) Installed Capacity(IC) = 2000 MW


c) Ex Bus Capacity/LTA for the station = 1875 MW



Andhra Pradesh 9.01

Karnataka 19.97

Kerala 21.35

Tamil Nadu 24.87

Telangana 10.96

Puducherry 3.68

Orrissa 10.00

HVDC-Talcher 0.08



respective month.

4. NTPC Simhadri STPS Stage II



c) Ex Bus Capacity/LTA for the station = 942.5 MW




Karnataka 20.87

Kerala 9.09

Tamil Nadu 22.33

Telangana 24.70

Puducherry 1.61

HVDC-Pugalur 0.31

HVDC-Thrissur 0.12



respective month.


5. NTECL Vallur STPS






Andhra Pradesh 5.74

Karnataka 10.83

Kerala 3.33

Tamil Nadu 70.99

Telangana 7.27

Puducherry 1.83



respective month.

6. NLC TS II Stage I


b) Auxiliary Consumption=10%

c) Mines loads= 7.94%

d) Ex Bus Capacity/LTA for the station = 521.98 MW

e) MoP Allocation of Power to the Entities:


Andhra Pradesh 8.05

Karnataka 25.08

Kerala 10.86

Tamil Nadu 32.56

Telangana 10.18

Puducherry 13.26

f) Monthly LTA to the DICs in MW =


respective month.


7. NLC TS II Stage II



c) Mines loads= 5.95%

d) Ex Bus Capacity/LTA for the station = 711.02 MW

e) MoP Allocation of Power to the Entities:



Karnataka 24.79

Kerala 11.4

Tamil Nadu 35.68

Telangana 13.41

Puducherry 3.89

f) Monthly LTA to the DICs in MW =


respective month.

8. NLC Stage I Exp.






Andhra Pradesh 0.00

Karnataka 25.79

Kerala 16.37

Tamil Nadu 53.92

Telangana 0.00

Puducherry 3.93



respective month.


9. NLC Stage II Exp.






Andhra Pradesh 0.00

Karnataka 25.79

Kerala 16.37

Tamil Nadu 53.92

Telangana 0.00

Puducherry 3.93



respective month.

10. NTPL







Karnataka 21.16

Kerala 7.25

Tamil Nadu 41.25

Telangana 15.06

Puducherry 3.14



respective month.







Andhra Pradesh 4.12

Karnataka 8.44

Kerala 5.23

Tamil Nadu 75.20

Telangana 5.11

Puducherry 1.89


12. NPCIL, Kaiga GS Stage-I







Karnataka 31.35

Kerala 8.64

Tamil Nadu 27.10

Telangana 15.78

Puducherry 4.59

13. NPCIL, Kaiga GS Stage-II







Karnataka 33.85

Kerala 7.96

Tamil Nadu 23.92

Telangana 16.76

Puducherry 4.14







Andhra Pradesh 0.00

Karnataka 23.37

Kerala 14.05

Tamil Nadu 58.90

Telangana 0.00

Puducherry 3.68



e) Installed Capacity(IC) = 1000 MW

f) Auxiliary Consumption=7.8%

g) Ex Bus Capacity/LTA for the station = 922 MW

h) MoP Allocation of Power to the Entities:


Andhra Pradesh 0.00

Karnataka 22.10

Kerala 13.30

Tamil Nadu 56.25

Telangana 5.00

Puducherry 3.35

vi. CGS connected to only STU system:


TANTRANSCO STU system:

a) 230 kV Acharpakkam – MAPS line

b) 230 kV Echur- MAPS line

c) 230 kV SP Koil- MAPS line 1

d) 230 kV SP Koil- MAPS line 2


vii.CGS connected to both ISTS & STU system:

1. NPCIL, Kaiga GS Stage- I & II

A. KPTCL STU system:

a) 220 kV Kadra-Kaiga

b) 220 kV Kodasalli-Kaiga

B. ISTSConnectivity:

a) 400 kV Kaiga - Guttur D/c

b) 400 kV Kaiga - Narendra D/c



2. NTPC RSTPS Stage I, II & III

A. TSTRANSCO STU system:

a) All 220 kV lines emanating from the 220 kVbus of 400 kV ICT 1 at RSTPS

b) All 220 kV lines emanating from the 220 kVbus of 400 kV ICT 2 at RSTPS

c) All 220 kV lines emanating from the 220 kVbus of 400 kV ICT 3 at RSTPS

d) All 220 kV lines emanating from the 220 kVbus of 400 kV ICT 4 at RSTPS

e) All 220 kV lines emanating from the 220 kVbus of 400 kV ICT 5 at RSTPS

f) 400 kV Dichipally- RSTPS line

B. ISTS connectivity:

a) 400 kV RSTPS- Gajwel

b) 400 kV RSTPS- Warangal

c) 400 kV RSTPS- Ghanapur D/c

d) 400 kV RSTPS – Malkaram



3. NLC TS-II Stage- I & II

A. TANTRANSCO STU system:

a) 230kV NLC(TN)- NLCSTII line 1

b) 230kV NLC(TN)- NLCSTII line 2

c) 230 kV Kadalangudi – Neyveli Stg1

d) 230 kV STCMS- Neyveli Stg I

e) 230 kV Ulundurpet- Neyveli Stg I


a) 400 kV NLC TS II- Pugalur

b) 400 kV NLC TS II - Nagapattinam PS

c) 400 kV NLC TS II - Salem

d) 400 kV NLC TS II - NLC TS I Exp.

e) 400 kV NLC TS II - NLC TS II Exp.




4. NTECL Valllur STPS


400 kV NTECL- NCTPS D/c


a) 400 kV NTECL- Kalvinthapattu D/c

b) 400 kV NTECL- Almathy D/c


5. KKNPP Unit- 1 & 2


a) 230 kV KKNPP- SR Pudur

b) 230 kV KKNPP - Tuticorin TPS


c) 400 kV KKNPP- Tirunelveli D/c

d) 400 kV KKNPP- Tirunelveli

e) 400 kV KKNPP- Tuticorin PS



6. NTPC Simhadri STPS Stage-I & II

A. APTRANSCO STU system:

a) 400 kV Kalpakka- Simhadri Stage-1 line 1

b) 400 kV Kalpakka- Simhadri Stage-1 line 2

c) 400 kV Kalpakka- Simhadri Stage-1 line 3

d) 400 kV Vemagiri- Simhadri Stage-I


a) 400kV Simhadri Stage II - Gajuwaka D/c

b) 400kV Simhadri Stage II – Vemagiri PG D/c

C. 400 kV Simhadri Stage I –Simhadri Stage-II Interconnector



7. NTPC Kudgi STPS Stage I

A. KPTCL STU system:

All 220 kV lines emanating from the 220 kV Kudgi-PG Bus from the 400 kV

ICT 1 & 2 at Kudgi NTPC


2 No.s of 400 kV Kudgi (NTPC) - Kudgi (PGCIL) D/c


8. NNTPS


230 kV NNTPS- NLC(TN) D/c


a) 400 kV NNTPS- Kalvintapattu

b) 400 kV NNTPS - Pugalur

c) 400 kV NNTPS - Salem

d) 400 kV NNTPS - Puducherry


viii. ISGS connected to STU & ISTS :

UPCL

(CERC Order dated 30.06.2016 in Petition No.10/SM/2014 &Order dated

19.12.2017 in the Review Petition No. 60/RP/2016):

KPTCL System:

a. 400 kV UPCL- Hassan D/c Line

b. 220 kV UPCL-Kemar D/c line


ISTS:

400 kV Hassan- Mysore D/c


Summary of the Joint Studies Meeting of the LTA-SubGroup held on 02.11.2021 1/6

SOUTHERN REGIONAL POWER COMMITTEE BENGALURU

Summary of the Joint Studies Meeting of the LTA Sub-Group held on-line on 02.11.2021

1. As decided in the first meeting of the LTA Sub-Group held on 29.10.2021, a joint study

meeting was held on 02.11.2021 by its members. The list of participants is given at Annexure-I.

2. In the meeting held on 29.10.2021, the following methodology was agreed for conducting the studies on all eligible Central Generating Stations (for whom no LTA is in place) deserve to be treated under Regulation 13 (11) of CERC’s ISTS Sharing Regulations, 2020:

Annexure III - Page 1 of 64Annexure CS.1 (Page 50 of 144)


3. The following CGS have been identified for conducting the studies:

SN Name of the CGS considered for study

1 NPCIL, MAPS, Kalpakkam 2 NLC TPS II Stage I 3 NLC TPS II Stage II 4 NTECL, Vallur TPS 5 NPCIL, KKNPP Unit-I 6 NPCIL, KKNPP Unit-II 7 NTPC Ramagundam STPS Stage I & II 8 NTPC Ramagundam STPS Stage III 9 NPCIL, Kaiga GS Stage-I 10 NPCIL, Kaiga GS Stage-II

4. The LTA quantum to be considered for various Beneficiaries in all CGS identified for

conducting the studies has been derived as per above methodology, and is given below:



State/ Beneficiary

RSTPS RSTPS NLC

TPS- II NLC

TPS- II NTECL MAPS KGS KGS KKNPP KKNPP

Stg. - I&II Stg.-III Stg.-I Stg.- II Vallur STPS 1&2 3&4 Unit-1 Unit-2

(E) Ex Bus Shares Andhra Pradesh 291.67 74.25 48.14 88.74 83.55 16.35 55.84 59.72 0.00 0.00

Karnataka 376.25 95.96 90.40 122.96 113.01 27.06 113.72 125.30 239.72 239.72 Kerala 267.20 67.28 67.80 96.23 50.57 21.46 40.01 36.85 144.27 144.27 Tamil Nadu 512.58 130.15 189.42 283.34 1054.66 305.15 110.56 95.82 501.68 501.68 Telangana 340.88 86.78 56.26 103.71 97.66 19.11 65.25 69.79 0.00 0.00 Puducherry 54.53 14.34 69.96 16.04 6.79 4.67 8.42 6.32 36.34 36.34 Orissa 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Goa 109.06 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Firm Shares_Total 1952.16 468.75 521.98 711.02 1406.25 393.80 393.80 393.80 922.00 922.00

5. NTPC Ramagundam STPS Stage I & II:

CTU: The total evacuation system had been executed by the Generator itself, i.e NTPC. Hence CTU did not have the relevant data that pertains to that period. Additionally, the life of the Generator also crossed more than 25 years. Hence, Telangana while considering all the facts may share the details, they had with them. Telangana: Station Units were commissioned in the year 1983-84. Two 400/132 kV ICTs were commissioned in the year 1983 and 1984. Initially, there were two 132 kV lines from 400/132 kV ICTs [200 MVA capacity] and three 220 kV lines from 400/220 kV ICTs [2 ICTs of 250 MVA and one ICT of 315 MVA capacity]. Subsequently, in the year 2016, one 400/132 kV ICT got failed and it had been upgraded to 400/220 kV ICT. Therefore, one of the 132 kV line got shifted to 220 kV. SRPC: stated that for the studies 400kV Dichipally line should not be considered as it was commissioned in the year 2008. Further Stage-III shall not be combined with Stage-I & Stage-II. Conclusion: Considering all above into account, studies were conducted as per the agreed methodology. Through studies, adequacy of Telangana STU system to evacuate Telangana share of around 340 MW from NTPC Ramagundam Stage -I and II was found to be in order. 6. NTPC Ramagundam STPS Stage III:

CTU: As per the planning data, no evacuation has been planned through 220 kV systems. As per the 9th Standing Committee meeting, Stage -III have been planned to evacuate through the 400 kV system and not considered the 220 kV system. Hence, the Stage III shall not be treated under this category. SRPC: seconded CTU’s view.



Telangana: stated that they would further conduct studies considering the CTU’ s perceptive and the results/ further conclusions, if any, would be shared. Conclusion: In line with the agreed methodology, NTPC Ramagundam Stage-III was not considered for conducting the studies, since its evacuation had been planned/ designed through 400 kV network. 7. Neyveli TPS -II Stage -I:

TANGEDCO: Studies have been carried out considering both Stage I & II since the power has been evacuated through the combined evacuation system. Present evacuation system has been considered in order to establish that the combined shares can be evacuated through the system. Also stated that N-1 constraint should not be considered, and studies should be conducted to ascertain whether their share can be evacuated through the existing STU system. SRPC: stated that the evacuation system which had been originally planned needs to be considered, and Stage-I and-II needed to be studied separately. CTU: seconded SRPC’s view. SRLDC: It depends upon the CTU’s decision and they have no comments. Conclusion: Considering all above into account, studies were conducted as per the agreed methodology. Through studies, adequacy of Tamil Nadu STU system to evacuate Tamil Nadu share of around 189 MW from NLC TPS-II Stage -I was found to be in order. 8. Neyveli TPS -II Stage -II:

TANGEDCO: Studies have been carried out considering both Stage I & II since the power has been evacuated through the combined evacuation system. Present evacuation system has been considered in order to establish that the combined shares can be evacuated through the system. Also stated that N-1 constraint should not be considered, and studies should be conducted to ascertain whether their share can be evacuated through the existing STU system. CTU: As per the PIB approval, 400kV lines have been identified for evacuation of power from Stage-II. Hence Stage II cannot be treated under this category. SRPC: enquired whether TN share from Stage-II can be drawn at some other drawl point connected to ISTS network. While Tamil Nadu replied in negative, CTU clarified that the ICT’s between Stage-I & Stage-II are meant for exporting other beneficiaries’ share from Stage-I.



Conclusion: In line with the agreed methodology, NLC TPC-II Stage-II was not considered for conducting the studies, since its evacuation had been planned/ designed through 400 kV network. 9. NTECL Vallur TPS: CTU: In the Minutes of 27th Standing Committee, interconnecting line between Vallur JV and North Chennai TPS-II Projects was not identified as a part of the Evacuation System. It had been stated that the line has been built for evacuation and reliability of Vallur JV TPS power, 50 % of transmission charges for this line would be pooled in the SR pool. Therefore, this station cannot be treated under this Category. Further, while evaluating (N-1) requirement, reduction in LTA quantum should not be allowed to make justice for the investment made in concerned ISTS.

SRPC: seconded CTU’s view that NTECL Vallur – NCTPS-II D/C line cannot be considered as evacuation path for NTECL. However, added that since the investments were made in both ISTS and intra-STU evacuation networks, reduction in LTA quantum by a suitable value so as to fulfil (N-1) criterion should be considered, if required. Also stated that the flows on this line would vary depending on the generation available from NTECL-Vallur and NCTPS Stage-II, and under normal operating conditions, with generation at both stations, the line would be mostly floating.

Conclusion: In line with the agreed methodology, NTECL Vallur was not considered for conducting the studies, since its evacuation had not been planned/ designed through 400 kV NTECL Vallur – NCTPS Stage-II D/C line.

10. NPCIL Kudankulam NPP Unit-I & Unit-II: CTU: In the Minutes of 18th Standing Committee, it has been clearly mentioned that the 220 kV connectivity’s were planned for the start-up arrangement. 400kV Transmission System have been identified as the Evacuation System for Kudankulam GS. Therefore, this station cannot be treated under this Category.

SRPC: seconded CTU’s view. Conclusion: In line with the agreed methodology, NPCIL Kudankulam Unit-I & Unit-II was not considered for conducting the studies, since the intra-STU network was basically meant for start-up power arrangement, and was supposed to be kept isolated from Kudankulam NPP during other times. 11. NPCIL Kaiga Stage-I & Stage-II: CTU: In the Minutes of 16th Standing Committee, only 400 kV transmission system were planned. It has been found that LILO of 220 kV Kadra- Kodasalli Line was provided due to the



delay in the commissioning of 220 kV Kaiga- Sirisiri line-1 and 2. It was an interim arrangement. Kadra, Kodasalli and Nagjheri stations being a generating station cannot be utilized to evacuate the Kaiga generation. SRPC: seconded CTU’s opinion. Added that even otherwise also, the existing intra-STU system, viz., 220 kV Kodasally – Nagjheri D/C line, most of the times is kept open by KA-SLDC due to operational constraints; and without strengthening the same, it cannot be expected to be closed). Hence, it also cannot be counted as evacuation path for Karnataka from Kaiga GS. PCKL: Requested to provide one more opportunity to present their case in the next meeting. Conclusion: In line with the agreed methodology, NPCIL Kaiga GS Stage-I & Stage-II was not considered for conducting the studies, since its evacuation had been planned/ designed through 400 kV network.

12. NPCIL MAPS

SRPC: Stated that since the evacuation Network of MAPS is fully intra-STS, there was no need to conduct any study since its adequacy to evacuate TN’s share is beyond doubt. However, whether the case of MAPS falls/ needs to be treated under Regulation 13 (11) of CERC Sharing Regulations, 2020 may be properly seen since there is no physical ISTS Network. Since this appears to be a special case, requested Tamil Nadu to examine the same, and present their view in the next LTA SubGroup meeting/ TCC meeting for further deliberation. CTU: seconded SRPC’s view. Stated that it has to be treated under a special category. Conclusion: MAPS case is not to be treated as that of a CGS connected to both ISTS & Intra-STS, but to be treated as a special case.

13. In this regard, the following are enclosed for kind reference:

a) Study results & comments received from Telangana received vide mail dated 03.11.2021 is given at Annexure-II.

b) Study results & comments received from Tamil Nadu received vide mail dated 03.11.2021 is given at Annexure-III.

c) Relevant Standing Committee Minutes provided by CTU received vide mail dated 05.11.2021 is given at Annexure-IV.

14. The meeting ended by agreeing that the above results would taken for deliberations in the next meeting of the LTA Sub-Group proposed to be held on 11.11.2021.

****


Annexure-I

List of participants for Joint Study Meeting of LTA Sub-group held on 02.11.2021


SL. NO Name of the Participant Designation Organisation Email ID

1 Smt. P Jyostna Rani Executive Engineer/Regulatory Affairs APTRANSCO [email protected]




5 Smt. Latha S.V AEE KSEBL [email protected]


7 Shri. T. Subbarayan SE TANTRANSCO [email protected]








15 Shri Sanny Machal Manager NLDC [email protected]

16 Shri NRLK Prasad Member Secretary (I/C) SRPC [email protected]























Joint Study Meeting of LTA Sub-Group of Southern Region , Dt:02-11-2021

SLDC/TSTRANSCO

Annexure-II

Page 1 of 7


Stage Unit capacity Date of

commissioning

Remarks

I Unit -I 200 MW Nov 1983 Stage-I & II

I Unit -II 200 MW May 1984

I Unit -III 200 MW Dec 1984

II Unit- IV 500 MW Jun 1988

II Unit -V 500 MW Mar 1989

II Unit -VI 500 MW Oct 1989

III Unit -VII 500 MW Aug 2004 Stage-III

Details of NTPC Ramagundam Generation:

TSTRANSCO Share of about 420 MW( 335.85 MW Stage-I &II and 84.15 MW from Stage-III as per billing period Aug-2021 ISTS Sharing Reg.)

Annexure-II

Page 2 of 7


S.No Name of the STU

Element

Capacity Date of

commissioning

Remarks

1 132KV NTPC-RSS-1 Panther 25-11-1983 Converted to twin

Moose

2 132KV NTPC-RSS-2 Panther 01-06-1984 Converted to twin

Moose

3 220KV NTPC-RSS-1 Moose 24-11-1989

4 220KV NTPC-RSS-2 Moose 13-12-1990

5 220KV NTPC-RSS-3 Twin Moose 24-08-1997

6 220KV NTPC-RSS-4 Twin Moose 23-11-2016 200 MVA 400/132KV

ICT-2 is upgraded to

315 MVA 400/220KV.

7 400KV Ramagundam-

Dichpally

Twin Moose 30-03-2008

The list of the TSTSTRANSCO transmission elements commissioned as a part of NTPC Ramagundam:

Annexure-II

Page 3 of 7


As can be seen above, TSTRANSCO(erstwhile APSEB) has developed its

Intra State Transmission Network to evacuate its share as per the corresponding commissioning years of the Units at Ramagundam STPS in Stage – I and Stage-II in the years 1983-84 and 1988-89 respectively. Although Stage –III(Unit-7, 500MW) commissioned in 2004, TSTRANSCO has adequate 220KV network in place before itself for stage –II evacuation . However Intra state 400kV network(400KV Ramagundam-Dichpally) is added in 2008 even though not specifically for Stage-III evacuation. Also studies are shown that entire NTPC Ramagundam share of TSTRANSCO about 450 -500 MW (335.85 MW +84.15 MW as per Aug-2021 billing period of Sharing Regulations-2020) share in Ramagundam STPS is evacuated through State Network Itself satisfying N-1 contingency . Hence the NTPC Ramagundam case falls under ISTS 2020 regulation – clause13( 11).

Annexure-II

Page 4 of 7


Bus # 424002 RSTPS NTPC 400.00

Type 2 Area 4202 RGM-TPS Zone 4202 RGM-TPS

Voltage 1.00000PU 400.000KV

Angle(deg) 16.42Remote Bus


T1

-89.8

28.2

* 90.3

-81.2

T2

-89.8

28.2

* 90.3

-81.2

T3

273.3

-95.3

* -270.4

14.0

T4

273.3

-95.3

* -270.4

14.0

T1

* 408.9

-122.7

-404.1

92.2

T1

407.8

-85.4

* -403.6

57.0

T1

* 201.3

-52.4

-200.5

5.9

T1

309.3

-86.7

* -305.7

7.6T1

-489.1

-25.8

* 497.0

13.2

T2

-489.1

-25.8

* 497.0

13.2

Q1

Q2

T1180.0

-67.7R

T2180.0

-67.7R

T3180.0

-67.7R

T4320.0

-120.3R

T5320.0

-120.3R

T6320.0

-120.3R

T7470.0

-176.7R

424002RSTPS NTPC

1.00400.0

414007TALLAPALLI

1.03410.4

414007TALLAPALLI

1.03410.4

424003GHANAPUR

1.01405.1

424003GHANAPUR

1.01405.1

424007DICHIPALLI

1.02408.7

424008GAJWEL

1.01403.9

424010WARANGAL

1.00400.9

424011MALKARAM

1.01402.8

424014BHADRAWATHI

1.02409.5

424014BHADRAWATHI

1.02409.5

424036TSTPP_NTPC

1.00400.0

424036TSTPP_NTPC

1.00400.0

SW

-0.0

-129.0

10.5

* 129.4

-0.0

421054RAMGUTPC

1.00132.0

11.00

0LK

LK

1

-167.9

10.9

* 168.5

3.3

-167.9

10.9

* 168.5

3.3

-212.9

15.8

* 213.8

2.3

-212.9

15.8

* 213.8

2.3

422010RAMGUTPC

1.00219.7

11.00

0LK

LK

2

422010RAMGUTPC

1.00219.7

11.00

0LK

LK

3

422034NTPC 220 BUS

1.00219.7

11.00

0LK

LK

4

422034NTPC 220 BUS

1.00219.7

11.00

0LK

LK

5

1

Annexure-II

Page 5 of 7





Angle(deg) -2.81

Remote Bus Bus # 424002

RSTPS NTPC 400.00

T1

T2

T3

T4

T1

T1

T1

T1T1

T2

Q1

Q2

T1

T2180.0

T3

T4

T5

T6320.0

T7

4.5R

8.1R

424002RSTPS NTPC

1.00400.0

414007TALLAPALLI

1.02409.8

414007TALLAPALLI

1.02409.8

424003GHANAPUR

1.01403.6

424003GHANAPUR

1.01403.6

424007DICHIPALLI

1.02409.1

424008GAJWEL

1.01403.5

424010WARANGAL

1.00400.5

424011MALKARAM

1.00401.1

424014BHADRAWATHI

1.02409.5

424014BHADRAWATHI

1.02409.5

424036TSTPP_NTPC

1.00400.0

424036TSTPP_NTPC

1.00400.0

SW

0.0

-99.3

4.3

* 99.5

1.9

421054RAMGUTPC

1.00131.8

11.00

0LK

LK

1

-122.2

3.8

* 122.5

3.7

-122.2

3.8

* 122.5

3.7

-155.0

6.3

* 155.5

3.3

422010RAMGUTPC

1.00219.5

11.00

0LK

LK

2

422010RAMGUTPC

1.00219.5

11.00

0LK

LK

3

422034NTPC 220 BUS

1.00219.5

11.00

0LK

LK

4

422034NTPC 220 BUS

1.00219.5

11.00

0LK

LK

5

1

Annexure-II

Page 6 of 7





Angle(deg) -3.70

Remote Bus Bus # 424002

RSTPS NTPC 400.00

T1

T2

Q1

Q2

T2180.0

T6320.0

T4

T3

T1

T1

T1

T1

T1

T2T7

T5

T4

T3

T1

3.2R

5.7R

424002RSTPS NTPC

1.00400.0

414007TALLAPALLI

1.02409.8

414007TALLAPALLI

1.02409.8

424003GHANAPUR

1.01403.6

424003GHANAPUR

1.01403.6

424007DICHIPALLI

1.02409.1

424008GAJWEL

1.01403.5

424010WARANGAL

1.00400.6

424011MALKARAM

1.00401.1

424014BHADRAWATHI

1.02409.5

424014BHADRAWATHI

1.02409.5

424036TSTPP_NTPC

1.00400.0

424036TSTPP_NTPC

1.00400.0

-83.8

2.6

* 84.0

1.8

421054RAMGUTPC

1.00131.8

11.00

0LK

LK

1

-91.5

2.2

* 91.7

2.0

-91.5

2.2

* 91.7

2.0

-116.1

3.9

* 116.3

1.5

-116.1

3.9

* 116.3

1.5

422010RAMGUTPC

1.00219.6

11.00

0LK

LK

2

422010RAMGUTPC

1.00219.6

11.00

0LK

LK

3

422034NTPC 220 BUS

1.00219.6

11.00

0LK

LK

4

422034NTPC 220 BUS

1.00219.6

11.00

0LK

LK

5

1

Annexure-II

Page 7 of 7


First meeting of the Sub-group to formulate a philosophy on LTA quantum of the

generating stations connected to both ISTS and intra-State transmission system-

Comments and views of TANGEDCO and System study results as per the methodology

proposed in the first meeting of the subgroup of TCC

1) In the first subcommittee meeting, after detailed discussion on the issue of

excluding the deemed LTA of TANGEDCO considered for allocation of ISTS

charges and losses in respect of MAPS, NLC TPS II- Stage I&II, NTECL Vallur and

Kudankulam ISGS, CTU proposed that in the absence of any specific procedure

for conversion of CGS allocation to LTA, if SRPC forum recommends a rational

formulae, the same would be considered for implementation. It was further

suggested by CTU that ISTS in order to ascertain the adequacy of intra state

network to evacuate their share from a CGS, the ISTS network connected to CGS

may be taken out of service and CGS may be left connected with inta-STS

system of the home state. If home state STU system is meeting all the criteria as

per the transmission planning criteria to evacuate their share, then that quantum

may be considered for exemption in the computation of transmission charges.

2) In this context, TANGEDCO submitted that the methodology adopted in the

cases of IGSTPS Jajjar, KBUNL, NTPC Simhadri St-I, NTPC Meja, RGPPL shall be

applicable in the case of TANGEDCO and hence may be adopted. Further,

TANGEDCO submitted that N-1 criteria need not be considered to assess the

capacity of Intra State network. Further, the sharing mechanism during the

approval process of the evacuation system and the present Sharing mechanism

are entirely different hence, it would be proper to consider the present status of

the intra state network and exempt the deemed LTA quantum in line with the

provisions of the Regulation 13(11) of the Sharing Regulations, 2020.

3) However, the subcommittee decided to conduct studies under the following

categories:

Annexure-III

Page 1 of 16


SlNO Rest of the System Intra-STS Evacuation System

1 Latest ATC/TTC All India Peak Base Case as on Date

i. Evacuation System originally approved


Date

2 ATC/TTC All India Peak Base Case as

on 01.11.2020

i. Evacuation System

originally approved


01.11.2020

3 The surrounding area Network (only) present at the time of approval of originally planned intra-STS

evacuation system

i. Evacuation System

originally approved

4) The sub group has formulated a methodology / procedure for conducting studies

under the above three scenarios. It is stated that in respect of case 3(i), no

formal study is required as the adequacy of Intra State network for evacuating

home state share may be checked after excluding ISTS system.

5) In this context, TANGEDCO has been reiterating the fact that the legitimate claim

of TANGEDCO to exclude the deemed LTA quantum in respect of the four ISGS

stations Viz. MAPS, NLC TPS II- Stage I&II, NTECL Vallur and KKNPP on par with

the cases exempted by NLDC based on the order of CERC and in line with the

provision under Sharing Regulation, 2020. Further, it was reiterated that N-1

condition after opening all the ISTS lines would be a hypothetical case and would

never occur in real time. If there is any constraint during contingency conditions

for evacuating power through the State network, then the ISTS charges shall be

allocated during the contingency period. It is further stated that the transmission

charges of the all the ISTS lines connected with these ISGS are billed to

TANGEDCO in the ratio of LTA+MTOA irrespective of usage of the lines.

Annexure-III

Page 2 of 16


6) Despite all the above facts, TANGEDCO conducted system studies for the

following cases:

(i) As per the decision of the subgroup no study is required in the case of

MAPS since it is a clear cut case for exemption.

(ii) NLC TPS-I- Stage I

Installed Capacity(IC) = 630 MW b) Auxiliary Consumption=10% c) Mines

loads= 7.94% d) Ex Bus Capacity/LTA for the station = 521.98 MW e) MoP

Allocation of Power to the Entities:

Andhra Pradesh 8.05% Karnataka 25.08 % Kerala 10.86 % Tamil Nadu 32.56%

Telangana 10.18% Puducherry 13.26%

As per the guidelines of the subgroup, all the ISTS lines connected to Stage-I are

kept open. The generators are scheduled with the allocation of TANGEDCO at

Ex-bus. Two case studies are carried out ie.

(a)With all the Intra State lines in service- Case-I

(b)with outage on one line carrying maximum power-Case-II

The study results and comments and observations of TANGEDCO are

furnished below:

Feeder Name Power flow in MW Remarks

Case -I Case -II The transmission lines

approved by the Standing

committee as part of the

evacuation scheme are

considered. The

transmission line capacity

is found adequate to

transfer the allocation from

Stage-I under normal

operating condition as well

as under outage of one

intra State line without

ISTS lines

Kadalankudi 93

STCMS -64 -52

Ulundupet 0 0

Neyveli TNEB 230

kV SS-Feeder-I 70 112

Neyveli TNEB 230

kV SS-Feeder-II 70 112

Annexure-III

Page 3 of 16


(iii) NLC TPS-I- Stage II

a) Installed Capacity(IC) = 840 MW b) Auxiliary Consumption=10% c) Mines loads=

5.95% d) Ex Bus Capacity/LTA for the station = 711.02 MW e)

b) MoP Allocation of Power to the Entities:

Andhra Pradesh 10.83% Karnataka 24.79% Kerala 11.4% Tamil Nadu 35.68 %


Since the Intra State transmission system for Stage I and Stage II are

through the common 230 kV bus of Stage I, both stage –I and Stage II

generating units are scheduled to ascertain the adequacy of combined

evacuation:






considered. The




Stage-I & II(combined)

under normal operating

condition as well as under

outage of one intra State

line without ISTS lines.

Kadalankudi 108 112

STCMS -36 -28

Ulundupet 0 0

Neyveli TNEB 230

kV SS-Feeder-I 180 348

Neyveli TNEB 230

kV SS-Feeder-II 180 0

*twin moose conductor in Neyveli TNEB SS feeders

(iv) NTECL Vallur STPS

a) Installed Capacity(IC) = 1500 MW b) Auxiliary Consumption=6.25% c) Ex Bus

Capacity/LTA for the station = 1406.25 MW

b) MoP Allocation of Power to the Entities:

Annexure-III

Page 4 of 16


Andhra Pradesh 5.74% Karnataka 10.83% Kerala 3.33% Tamil Nadu 70.99%


The Vallur- NCTPS Stage II 400 kV D/c line is part of the evacuation system of

Vallur TPS. The other ISTS lines connected to NTECL Vallur are kept open. The

allocation of TANGEDCO is scheduled keeping the Intra State lines in service. Full

generation at NCTPS Stage II is scheduled






considered. The




NTECL Vallur under normal

operating condition as well

as under outage of one

intra State line without

ISTS lines.

Kalivanthapattu-I 0 0

Kalivanthapattu-I 0 0

Alamathy -I 0 0

Alamathy -II 0 0

NCTPS St II-

Feeder-I 528 1056

NCTPS StII-

Feeder-II 528 0

(v) NPCIL,KKNPP UNIT I & II

Installed Capacity(IC) = 1000 MW b) Auxiliary Consumption=7.8% c) Ex Bus

Capacity/LTA for the station = 922 MW

Andhra Pradesh 0.00 Karnataka 23.37% Kerala 14.05% Tamil Nadu 58.90% Telangana

0.00% Puducherry 3.68%

Installed Capacity(IC) = 1000 MW f) Auxiliary Consumption=7.8% g) Ex Bus

Capacity/LTA for the station = 922 MW

Andhra Pradesh 0.00 Karnataka 22.10% Kerala 13.30 % Tamil Nadu 56.25 % Telangana

5.00% Puducherry 3.35%

Annexure-III

Page 5 of 16


Since the power from unit I&II is evacuated through the combined Intra State(the ICTs

are KKNPP are in regular service) as well as ISTS, combined study is conducted for

both units for the following cases:

Case-I :KKNPP without ISTS with 1004MW generation(Full allocation)

Case II : KKNPP without ISTS with 280MW generation

Case III: KKNPP without ISTS with 280MW generation with one Intra state line outage


Case -I Case -II Case -III With full allocation of

TANGEDCO, the 230

kV lines are not

adequate. Hence

under reduced

generation of 280

MW, the two intra

states lines are

adequate to cater the

power evacuation

under normal

scenario and under

outage of one intra

state line. Hence, a

quantum of 280 MW

may be excluded

from the deemed LTA

.

Thirunelveli 400 kV

D/C line 0 0 0

Thirunelveli 400 kV

S/C line 0 0 0

Tuticorin PS 400 kV

S/c line 0 0 0

SRPudur 230 kV S/c

line 649 213 0

TTPS 230 kV S/C line

339 61 273

Conclusion:

It is evident from the above study results that the intra state network connected

with MAPS, NLC TPSII- Stage I and II, NTECL Vallur are adequate to evacuate

the allocation of TANGEDCO from these stations and hence, the full allocation

shall be excluded from the LTA. In respect of KKNPP, a quantum of 280 MW may

be excluded from the deemed LTA as the capacity of the lines are adequate to

transfer this quantum. The study exhibits are enclosed.

Annexure-III

Page 6 of 16


1. NLC stage 1 with 2 Intra State lines

Annexure-III

Page 7 of 16


2. NLC stage 1 :Case-I- With 4 Intra State lines(without ISTS)

Annexure-III

Page 8 of 16


3. NLC stage 1: Case II- with 4 intra state lines and under outage of one Intra State line

Annexure-III

Page 9 of 16


4. NLC stage 1 &2 combined: Case-I- With 4 Intra State lines(without ISTS)

Annexure-III

Page 10 of 16


5. NLC stage 1 &2 combined: Case-II- With 4 Intra State lines(without ISTS) and outage of one Intra State line

Annexure-III

Page 11 of 16


6. NTECL – Case-I - Without ISTS line with full allocation of TANGEDCO

Annexure-III

Page 12 of 16


7. NTECL without ISTS with full allocation of TANGEDCO under outage of one Intra State line

Annexure-III

Page 13 of 16


8. KKNPP without ISTS with full allocation of TANGEDCO

Annexure-III

Page 14 of 16


9. KKNPP without ISTS with 280MW generation

Annexure-III

Page 15 of 16


10. KKNPP without ISTS with 280MW generation under

outage of one Intra State line

Annexure-III

Page 16 of 16


Celltral Efcctricily Author;ty

S)'stcl'n PJanriing < . ~ /\ ppnlisal D!v:slon

Scwa Blww;m. R.K.Puram.

Nc\\' Dcihi-IIOO(l).

No.5J/4198-SP& Iq93 Daled Ihe'" ~ ' : : 1998.

2.

3.

Gene Manager.

P 'er Grid Corpn. Of

n d i ~ LId.,

B-9.fnstillition:\! Are;:!.

S.S.J.c. Marg,

Katwaria Sarai,

New De1hi-llVj! 6.

Chief Ellgilleer(Trans.),

AP.Slate Elcc.\'. Board,

Vidyut Sondha,

Hyderabad-SOOO"·9.

Chief Ellgillccr (R&?)

Kcraia State E!cclrY. Board

Vidyuthi Bh;-n... a~",c.~m:Fallon!, P.B.No. JOn,

TlltlUV<lil(Uii\KijX;J , ~ r ; ! .

FIN - 69S00<.

.'

4. $upcrintcnding Enginccr-!

Elcc[ricity Dcp:.lrtlllcnLRoom No. j t) j. PitSl Flo<)f.

Gingy S ( l l a j . P o n d j c l 1 c r r y ~

PIN -605 00 l.

5. Member Secretary,

Southern RegJ.Elcey.Board

29, Race .. Course Cross

Road,Bangalore-S60 009.

6.· Chief Engineer (Elect.)

(l'FCIADB works)

K,1rnataka Elccy.Bo<~rd

Callvcrv Blw\VaiL

B a l l g a I ~ r e - S 6 0 009.

7. Chief Engineer (F'lg.)

Tamil Nadt: Ekcy. Boa;"Q

NPKRR MilaIiga;,

800. Anna Sai;li.

Chcnna;-GO(l (Iii!..

.'( Chicf Eng,inccr (ElcCl.)

'. C,'o General rv1anugcr..Pc"~'C;- St<i(ioll PJ~!Illlillg.

Corporille.OfTice,BJoek-I

Ne)'\'cli Lignite Corpn.,

P.O. Nc)'veli,

South Areol DisH

Tamil Nadu.

9 ~ ChicfEnginccr. ( T r ~ m s . )

Nudenr PO\ycr Corpn.Lld.

V i k r ~ l m Sarabhai ShawanoAnushakli N ; J g ~ l r .

[Vlll mba i - · . J . O O O Y · ~ .

10. GCJ18ra! r,:iaJl<ig,cr (Eject.)

NT?C Ud...

Engg. Oftic(' C > j ; : ~ p j c x .

. ~ \ ~ ~ L S'.:COl' 2-+.

NOIDf\- :W: ~\n L

Sub: f;-',inutes of the Ninth . i \ ' l e t ' { j j i ) ~ r,-,fSr;;ndiitj: (·;;E;n:iih':..' \:;, r , ~ : : 1 : ~ ' :

:-c:a!ing to POWCI" System P L ~ ! ; n . i i l ~ ~ I1.: :.i:'2.;·:': l><::i~J!:"

Sir,

Planning in SOll~h.:::r;: t<c~)on h(',ld at Thiruvail:l;i{:l<1;:'::i'::,;: '!:. ' . : - ~ ; : - ; : ~ ~ ~ ' , h :()S-..;(-! ;-\Y' yOtif

perusal p J c ~ ' . s e .

.-----=j'

Di;·l'C.tOj" ;"-;P&:\.)

'I't'LNo.Ol; < \ ; n , < ; l ~ i n

Annexure-IV

Page 1 of 34


Annexure-IV

Page 2 of 34


/.

SUMMARY RECORD OF 9TII

M.EETING OF THE. SlNiDING COMMITTEE ON MATTERS RELATING TO

. POWER SYSTEM PLANNING IN SOUTRERN REGION.HELD AT THIRUVANANTHAPURAM O N 4 ~ n I DECEMBER, 1998.

List of participants is enclosed atAnnex-1.

Chief Engineer (SP&A) welcomed all the participants to the Standing

Committee meeting and stated that the, meeting was primarily called to discuss

and finalise the transmission system associated with 7ti' unit (500 MW at

Ramagundam STPS) and also the transmission systcm rcquired ('or slrell!'thcllillg

oCthe Southern Regional grid to enilble the constituents to absorb the power

available from the Eastern and Western Regions. The agenda was thereafter

taken up for discussion.

I. Transmission system associated with Ramagundam 7°' Unit (500 MW) :

Chief Engineer (SP&A) stated that Central Electricity Authority had

already accorded techno-economic clearance for installation of iJdditional 500W

cap?city at Ramagundam STPS of NTPC. To enable POWERGRJD to

commissIon, the assoc.iated tnmsrnission systen1 to n1atc.h \\lith the. CO!~:::1issionjng

of generation, it was necessary that the system component be also iin21ised and

got· approved by POWERGRlD. For identifying the transmission system

associated witI-? this additional capacity, Central Electricity Authority had alre3dy

carried out transmission system planning studies. Considering tlmt the import of

power from the Western Region over the ChandrilPur-RamagundiJlll l i l l ~ which

was also 10 be translnitled over the transmission syslem ('rom Rall,agullcblll, the

studies had considered the import of power alongwitll full generation ,capacity at

Ramagundam STPS so· that the transmission system so planned is capable of

utilising the Cull quantum of power at Ramagundam alongwith import i"om the

Western Region. Further, another project near Ramagundam to, be im!)iemented

by M/s.BPL with a capacity of' 520 1vIW had also been accorded teclll;o-economic

clearance of Central Electricity Authority. For evacuation of power fi·ol11 this

project, APSEB was separately implementing associated transmission system

. which inter alia covers the following transmission facilities:

i)

ii)

iii)

BPL - Diehpally

BPL - Gaijwet-Hyderabacl.

B ~ L - · Ramagundam

400 kV SiC

400 ~ V SIC

220 kV ole

He added that the results of the studies carried out by Central Electricity

Authority had already been brought out in the agenda paper and the same had

.been circulated to all thc constitucnts.

Annexure-IV

Page 3 of 34


Discussing the r ~ s u l t s ' of studies carried out, .it. was pointed out by CE

(SP&A) that an additional SIC Iin~ from Ramagundam to Hyderabad and onwards

to Gooty was considered and it was found that with this line and considering full

generl!tion in the northern part of the Southern Regional grid .(including full

. generation at Ramagundam, import from Western Region, full generation at

Simliadri a'nd Vizag complex including import from EasternRegion) the loading

on the Ramagundam-Gooty corridor was satisfactory. However, the 400 kV

Ramagundam-Kharnmam line was not evacuating any power from Ramagundam

and on the contraly illjecting the power from Simhadri"Vizag complex towards

Ramagundam and the Gooty-Bangalore line was also getting overloadcd.

Accordingly, it was felt that in addition to the line from. Ral1lagtindam-Gooty via

Hyderabad ,the follQwing additional cjrcuits would also be required for reliable

evacuation of power from Ramagundam:

i)

ii)

Khammam-Nagarjun,\sagar

Gooty-Bangalore

400 kV SIC

400 kV SIC

Chief Engineer (SP&A) further stated that in' addition to the above

transmission facilities, the LILOof 400 kV Vijayawada-Srisailam D/C line, being

constructed by APSES, at Nagarjunasagar, and creation of 400 kV Substation at

Kalwakurthy by LILO of the Hyderabad-Srisailam 400 kV SIC line and

Nagarjunasagar-Gooty 400 kV SIC line as weI) as the LILO o f N a g a ~ i u n a s a g a r

Gooty 400 kV SIC line at Karnool and the Hyderabad-Gooty (proposed above)

line at Karnool would be required. It w'!s observed that the !lbove arrangements

resulted in reduction of about 170 MW in the lotal system losses. He requested

the constituents to give their comments.,

-'

Executive Director( Engg.), POWERGRlD stated that it was necessary to

utilise the transmission. con'idors optinlally and hc , therefore. suggested lhat

instead of the 400 kV SIC line lI'om Raillagundam toHyderabad, a DIe: line shouldbe constructed. .

Chief Engincer , APSEB slaled that the LlLO of Vijayawada-Srisailalll al

~'\ Nagarjunasagar would need to be examined keeping in view the requirements of

pumping power at Srisailam during the oft:peak conditions. "He, thercCorc,

suggcsted carrying out of load flow studies corresponding to pumping modc oC

the SrisaiJam station beforc a decision was taken on thc LlLO of Vijayawacla

Srisailam at Nagarjunasagar.

Chief Engineer,KES-suggested that the loads around Chintamani , north

I'·t of Kolar wcre'de\leloping very fast and the second 400 kV line bctwcen Gooty

and Bangalore sliould be routed via Chintamani.

Chief Engineer, TNEB stated that thcre wos a nccd for strcngthening the

line bctween Cuddapah and North Madras by constnJcting an additional 400 kVline in the corri,for.

"0:,;.-

Annexure-IV

Page 4 of 34


;

iIi

i.

\'

;.'.,

>"{<"f~ik~l'i,'.",," '.... , ,,~.,',.,'. .." ; ,':,))" .:, }!L',';"::;,ii.'!'{?;,'8+0X'!'esfe'h Enginee;;:(SP&A)reSpondi~~·.,~;,::ilf(6d~~i~i~Of. ,.the·· .m~mb~rs

~!: ,. ,,' 'J s t a t ~ d , : i b ' a : t ' : f d f e v a c u a t i o n ; 6 f p o w e r f r o m R a m a g U ' l l , a J i i i : ~ r . ; a & d i t 1 0 n a I SIC line' was·.. ·t:ad~quate',;·consideririg>that.·; 'with <the , aclditionof .400.,kVKhammam -

":Nag~iJi,ina~agar 'line the Ramagundam-Khammanl. se<;ti'9rl.was carryirigrnore than

20QMW'imd' therefore;' the proposed' D/Clineby;PQWERGR1Dcould .be

.·.c()nsid~fedas a composite transmission system beingplanmid by APSEB asa part

. ofI3Pl.;TPSand thesharinii:&thecostofthis D/Cjine c()uld be mutually settled

between !'OWERGRlD and'APSEB 50 that the objective ofoptiillising the right-6f-wiiY was also achieved." .

"Keg'arding the establishment of a new substation atChintamani, he stated. that.,alieadya400'kV SUbstation;at Kolar was being established as pali of

. Talcher-II project and the ,new subs.tation could be implemented by KEB by LILO'. of4'OQ kV line ofPOWERGRID passing near the substation location, Regarding

,the'LILOofVijayawada-Srl'sailam atNagarjunasagar,Chief Engineer (SP&A),Central Electricity Aiitlionty' stated that Srisailam WaSCOIJIJected to Ramagundam

via'HyClerabad as w e l 1 ? a s N a g ~ j u ' n a s a g a r w h i c l i ; w o u l d provide the required

pumping power, in additiorilothepower from theSimhadri and Vizag complex,

As such the apprehensions about not meeting the pumping requirements of

Srisailam project did not hold good. However; he agreed to carry out the

aClditional studies for .•. off_peak load conditions to confirm the adequacy of

transmission for pumping mode at Srisailam project.

Regarding the proposalofTNEB for strengthening of the Cuddapah-NorthMadras -1ine he stated that the proposal was being discussed in the next point of

the agenda,

After further discussions the following transmission system'was finalise"

for evacuation or"power from the 7th

unit at Ramagundam STPS: \b'

';

i)

ii)iii)

iv)

Ramagundam-Hyderabad

Hyderabad-Karnool-GootyGooty-Bangalore(Nelamangala) .

Khammam-Nagarjunasagar

400 kV DIC line;,400 kVS/C 1/

400 kV SIC I

400 kVS/C!

It was also agreed that jf required one circuit of the Ramagunc!amHyc!craffiHI-400 kV Die title cnrl,be:ULtJc"tl At(jPL by :\I'Sr:ll "t their eOSf as this

"~ 'would provide reliabllily dhvtiblUlHbli o!'ptwM £ttl,,; the project.

Annexure-IV

Page 5 of 34


Anil-CTU

Rectangle

n.. 'Strcngthcning of thc t.r'lIlslIIiss;on systc.1II in thc

Southern Rcgional Grid:

Chief Engineer (SP&A) stated that APSES has planned ~ h e following

transmission system as a part of the generation planned at Simhadri complex: .

i)

ii)

Vizag-Rajamundry-Vijayawada-

Vizag-Khammam-Hyderabad -

AOO kV D/C

400 kV D/C

.,

.Chief Engineer (SP&A) informed that the above proposals had already

been accorded techno-economic clearance of C E A. However, it was now scen

that with the addition of gcncration capacity at Ramagt!ndam as well as r3PL TPS

the loads of Hyderabad would be very reliably met even considering the nlture

growth.in the area. He also stated that with the transmission system planned as a .

part of the Ramagundam Unit-7 the studies had indicated the loading of these

lines was only of the Order of about 250 MW per circuit. Accordingly, Central

Electricity Authority had carried out the studies by re-routing the Vizag

Khammam-Hyderabad line towards Nellore via Guntur. .

The studies showed that with this arrangement .not only the loads of

Hyderabad were being met but· also the loads in the southern part of Andhra

Pradesh were also being catered too. Further, extending this line towards North

Madras would strengthen the Southern Regional grid network and enablelito

import the full capacities on the back-to-back link with the Western and Southern

Regions. He, therefore, suggested that the following transmission system should

be developed,inlieu of the 400 kV Vizag-Khammam-Hyderabad line.

i)ii)

iii)

/iv)v)

Vizag-Guntur 400 kV DIC

Vijayawada-Guntur 400 kV DIC

GunturcNellore 400 kV D/C

. Nellore-North Madras 400 kV D/C

Nellore-Chittoor 400 kV SIC

(proposed under Krishnapatnam project)

APSEB

PGCIL

APSEr3

PGClL

APSEB

Chief Engineer, APSEB stated that the 400 kV Vizag-Khammam

Hyderabad line was proposed to be covered under OECF credit and any change in

the configuration may result in the withdrawl of loan Ii'om OECF. Further, in

view of the importance of meeting the loads around Hyderabad. APSEB

considered'it essenti;d to constllJct lines from alternatc sources. Accordingly they

. were not agreeable for review of the transmission system already approved ti-om

Simhadri complex considering the commitments given to the IPPs for evacuation

of power and the financial implications in not fiilfilling the same. He also stated

that the studies had proposed the 400 kV Nellore-Chittoor line withoutconsidering generation at Krishnapatnam .

Annexure-IV

Page 6 of 34


... ;,~ ....

Chief Engineer (SP&A), C E A stated that studies had indicated that

technically the proposal of Vizag-Guntur-Nellore 400 kV line was superior to

Vizag-KhanullilJn-Hydcrabad linc as the. /irst proposal would catcr to thc

increasing load demands in Southern part of Andhra Pradesh.' Further,

strengthening of Vijayawada-Nellore-North Madras corridor 'was "required to

enable the remotely located states of Tamil Nadu and Kerala to avail 'the power

imported from neighbouring Regions. Chief-Engineer,APSEB did not concur

with Chief Engineer (SP&A),. C E A for review of the transmission system

associated with Simhadri complex. CE (SP&A), Central Electricity Authority

stated that it was also considered necessary to construct a 400 kV line li'om

Chittoor towards Kolar for strengthening of transmission system to Karnataka.

Executive Director (Engg.), POWERGRlD stated that the power Ilowing on the

Chittoor-Kolar link was being transmitted further to Hosur in Tamil Nadu and

accordingly a line from Chittoor to Hosur could be considered. CE (SP&A) stated

that the alternative of the Chittoor-Hosur line was not examined and further

studies would be carried out to determine the feasibility of Chittoor-Hosur vis-A

vis Chittoor to Kolar.

ARer further discussions it was decided that in order In enable

lI'ansmission of Ihe power imported li'om the WeStern and Eastern Regions to

Tamil Nadu and Kerala and to provide another corridor to transfer power from

NorthcEast part· of Southern Region to southern parts, it was necessary to

strengthen the Southern Regional grid by construction of 400 k V D/C line

between Vizag and North Madras via: Nellore. In addition, it was also proposed 10

LILO the CUddapah"North Madras line at Chittoor. POWERGRlD would

undertake the project of strengthening of the regional grid and submit the

feasibility report to Central Electricity Authority covering the following

p r o p o s a l ~ :

i) Vijayawada-Nellqre 400 kV [)/C

ii) Nellore-North Madras 400 kV Die

iii) LILO ofVijayawada-Srisailam at Nagarjunasagar 2:dOO kV Die

iv) Chiuaor-Kolar (or) Chittoor-Hosur . 400kV SIC

1t was also decided thai the arrangement of Ihe 400 kV S"bslalinl1 ;>1

Kalwakurulhy would be implemented by APSEB by LILO of 400 kV Hyderabad

Srisailam SIC and Nagarjunasagar-Gooty SIC lines. Further, the LlLO of

Nagarjunasagar-Gooty line at Klinlool would also be carried ,jl!t by APSEB.

Establishment of 400 kV Substation at Chittoar and LlLO of C:uddapilh

Madras lillC at Chinoor would also be carried out by APSEB.

Chief Engineer, TNEB stated that the line from Chittoor-Hosul' may be

covered under Talcher pmject. CE (5P&A) stated Ihat the T:licher tr"nsmiss;on

system had been discllssed and finalised in the last meeting of the Standing

Committee and POWERGRID have accordingly processed the case for obtaining

",.

Annexure-IV

Page 7 of 34


/,I,

/

additional transmission system' would need (0 be covered under the strengthening

project as proposed now.

IT): Second feeding point for Kerala for· transfer of power fromCentral

Sector Projects:

Chief Engineer, KSEBstated that presently Kerala was supplied central

sector power at Tnchur North and through the Iamil Nadu's transmission system

over inter-State Hnes. Under certain conditions TNEB was disconnecting 220 kV

inter-State links resulting in difficulty for Kerala in absorbing its share of power.

In order to meet the requirements of Kerala he proposed construction bf 400 kV

line fj-om Mysore to Kozhikode under central sector. , CE (SP&A) stated that

studies hag been carried out for providing a second feeding point into Kerala and

the following two alternatives had been examined in this context:

Alternative-I:

Madurai-ThiruvananthapuramJPallom

Alternnative-II

Mysore-Kozhikode

400 kVD/C

400 kVD/C

\.

He stated that at present 400 kV Substation atMadurai under the central

sector was already existing and it was possible to construct a line 10

ThiruvananthapuramJPa]Jom substations. Further considering the number oflPPs

proposed at .Kasargode, Kozhikodeand Kannur and also keeping in view the

pattern of load demand in the northern and southern parts of Kerala, providing a

second feed point at Thiruvananthapuram was a better proposal. Further tbis line

could be LILOed at tbe proposed nuclear power project at Kudankulum, This

would also provide a direct interlink to Kerala from Kud ankulam project.

Regarding the second idternative he stated that the 400 kV substation a( Mysorc ~ >

was proposed as a part of the transmission systcm associatcd with M/s,('ngcntrix

project which was likely to be delayed. As the substation was linked up to the

establishment of 400 kV Substation of Mysore there was every possibility of this

getting delayed and accordingly it is proposed that the Alternative-I may be

adopted.

Chief Engineer, KSEB stated that there were uncertinities about the [PPs

coming in North K3l'iila and there was scope for substantial increase in the load in

thc area. He, therefore,felt that the secQl1d feed point to Kerala mil)' be provided

to Kozhikod<::, "He. also agrced that the details 01' load coming lip in the area along

wit.h.the details of the transmission system proposed would be intimated by KSEB

so that additional studies could be carried Ollt by the Central Electricity Authority

and final decision taken about the second injection point for Kerala, 'Ti", :~ ~ d.", II,u.;.

d t . i . . I · ~ & , . I . . t,;jLl'l..i.{ i...: <:t:'I~·II· ..(c;eJ( ';'y 1 ; I : ; ~ ~ ~ l ~ ' ; ~ ~ ' . D a_I.' }'L.~,'}j'··''''(:l.. .... y.\r"(';, .. :"l,1. ~ c

J ~ { v · t erl .<:i~·('~.tJIt.ilr)~:J 1- .t;'_{~·/lr""_~.\i/n -;.y-nUIlI. I < ; ~ <;..,• .ti,,:";/I.' - < ' : ~ / ) I ~ " -

Annexure-IV

Page 8 of 34


IV. Reactive Compensation:

CE (SP&A) stated. that it w;s. observed by Central Electricity Authority

that the existing' transmission facilities in the country were not being used

optimally due to very poor voltage profile it') the grid. This was primarily due to

inadequate reactive compensation provided in the grid. Though the need for

providing shunt capacitors was recognised, SEBs Were not able to give adequate

priority to this vital an~a due to res0•.'rce crur.ch. In order to ltClgment.the efforts of

the SEBs it was proposed that the Central Sector would also be involved in the

area for providing reactive compensation... Towards this end Central ElectIjcity

Authorlty had recently finalised certain guidelines for provision of reactive

compensation which have been circulated to all the SEBs and Central Sector

agencies. The guidelines circulated by' Central Electricity Authority cover thefollowing proposals:

• Reactive compensation to the extent of 75% of the new generationcapacity to be added in the grid :would need to be provided as a part of

the associated transmission system.

• In the case of projects being implemented by SEBs and IPPs, the

necessary reactive compensation wO\ild be covered as a part of the

associated transmission system to be implemented by SEBs.

• In the case of Central Sector projects, the requisite reactivecompensation would be covered as a part of the associated

transmission system to be implemented by POWERGRID..... ."

• Pewer 'Grid would instal the shunt capacitors in the beneficiary states

in proportion to their share in the generation project.

Chief Engineer (SP&A) stated that as POWERGRID would not be in a

position to implement the required: shunt capacitors at 11/33 kY. It was

proposed that POWERGRID would instal the capacitors at 132 kV or 66 kV

Substations. He, therefore, requested the SEBs to identify a few substations

where POWERGRTD could instal capacitors. The provision of capacitors would

be a one time effort by the POWERGRID and the subsequent O&M would be theresponsibility of the SEBs.

Chief rihgineer (SP&A) enqui;ed from the SEBs about the progress of the

. capacitor installation programme during 1998-99. Chief Engineer, TNEB statedthat about 500 MVAR capacitors was installed by November, 1998 andadditional 800 MV AR capacitors were likely to be installed before the end of thefinancial year.

.~

Annexure-IV

Page 9 of 34


",-

0,

! : ",

Chief Engineer, APSEB stated t h a ~ about 320 MYAR of capacitors was

already commissioned and there was a programme to commission an additional

340 MVAR in the next 3 months,

ChiefEngineer, KSEB stated that agreements have been reached between

POWERGRID for installation on turn key basis, Howev.er, there has been some

delay due to tying up ofPFC funds for the same.

Chief Er.gineer, KEB statec!that Karnatak2 iJacJ floated tenders lor

installation of 1000 MYAR on turn key basis.

Chief Engineer (SP&A). stated that the studiescaITied out by Central

Electricity Authority had indicated for import of 1000 MW fTom Western and

Eastern Regions, an additional reactive compensation of about 3900 MVAR was

required to be provided in the Southern Region. Tn view of the slow progress in

instalIati'on of reactive compensation, he .expressed his apprehensions about the

utilisation of the surplus power available in the neighbouring regions by the

constituents of Southern Regional grid. He requested them to expedite the

installation of capacitors to enable them to avail assistance from the neighbouring

Regions.

"

.- ,

Annexure-IV

Page 10 of 34


r·····LIST OF PARTICIPANTS

CENTRAL E·LECTRICITY AUTHORITY

I.Shri V. Ramakrishna, ChiefEngIneer (SI'&A)

2.Shri V.I. Talwar, Director (SP&A)

KARNATAKA ELECTRICITY BOARD

1. Shri N. Vijaya Bhaskar, Chief Engineer (E1ec.).,

ANDHRA PREDESH STATE ELECTRICITY BOARDI. Shri Gopalachary, Chief Engineer (400 kV Lines & SIS)

2. Shri A. Sai Prasad Sarma, SE

3.Shri M.Seetharama Sarma, DE/Power System Studies

KERALA STATE ELECTRICITY BOARD

I. Shri K.N.C.KuIUP, Chief Engineer (Research ,Plg.&REC)

2. Shri Jacob Mathew, CE (System Operation)

ANN I ~ X 1I RIC-I

.." ;" ~

[n Chair

TAMIL NADU ELECTRICITY BOARD

. I. Shri E. C. AlUnachalam, Chief Engineer (Pig.)

.'

NEYVELl LIGNITE CORPORATION OF INDIA LTD.

I. Shn Avudaithangam, Dy.ChiefEngineer (Power StnPlg.)

POWER GRID CORPN. OF INDIA LlIVIIn:O

1.Shri Sc. Misra, Executive Director (Engg.)

2.Shri Y.K.Sehgal, Chief Design Engineer (Engg.)

J.Shri Babu Varghese, Chief Manager. Kayamkulam.

NT PC

1. Shri A.K. Gupla. Chief design Engineer

2.Shri C.D.lvlurthy. DyChie!' Design l-:ngillccr

NUCLEAR POWER CORPORATION1. Shri Rajesh Laad. Suptg. r':llgilleer

SREB

I.Shri S. Sivan, Member Secretary

Annexure-IV

Page 11 of 34


/

Annexure-IV

Page 12 of 34


· .

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ms<rr: 51/4/2002 - ~.~.q 'f.~./. ~.:.3~, 01.2003

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Annexure-IV

Page 13 of 34


•(i/

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Date: 30'" Janua!y,2003. . ') ."",

'1 4iII

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. ,,' ~,' C{,:o't:cJE~{:d.ridtJ AUtl!u;dty

System Planning & Project Appraisal DivisionSewa Bhawan, R.K. Puram, New Delhi-loo 66.

NO.5114/SP&PA·200lf

To

I 1.111e Member Secretary, 2. Th~ Executive Director (Engineering).

Southern Regional Electricity Board, Power Grid COI]l. oflndia Ltd.

29, Racc Course Cross Road, B-9, Institutional Area, Katwaria Sarai,

Bangalore 560 009. New Delhi 110016.

FAX: 080-2259343 FAX: 011-6466823,6564751

.

3.Thc Director (fransniission). 4.1l1C Director (Transmission).

r ransmi.,ssion Corp. of Andhra Pradesh Ltd., ~ Karnataka State Power r ..nsmissiou Corp. Ltd.,

Vidyut Soudha, CaU\ocr)' Bhawan.

!!)'d=bad .. ' 500 082. - - BangeToc1fS6tl W9,;,,·~·~'_,,_~,-,"m . ~ ...- _......._....-,...' ....

FAX: 040-3317652, 3320565 FAX: 080 -2228367, ,221352

5.The Member (TranSmission), 6.The Executive Director! Planning,

Kerala State EjectricityBoard, Tamil Nadu Elcctricit)' Board,

Vidyuthi Bhawanam. PaUom. P.B. No. 1028, 6lh Fh:lOf, Eastern Wing, 800 Anna Salal,

1l1iruvananthapuram - 695 004. Cheonai - 600002.

FAX: 0 4 7 1 - 4 ~ 6 7 7 4 FAX: 044-8521210,8544528..- --

.... . -- .

7.The Director (power), 8.The Superintending Engineec -l'-Corporate Office, Block - I, First Floor, Electricity D c p a r t l 1 l c n ~

NeyvcIi Lignite C o r ~ . Ud.•,NeY\''eli. <3ingy Salai,

Tamil Nadu - 607 801. PondichefJY - 605 001.

FAX : 04142·526~6 FAX: 0413-334277

9.1he Executive Director (Engineering), lO.lIte Director (Transmission),

NTPC Ltd., Engg. Office Complex, Nuclear PowerCoI]l. of India' Ltd.,

A-8, Sector 24, 12th Fl(\('lr,North Wing..Vikram Sarabhai Bhawan, _

Noida - 201 301. Anushakti Nagar,..FAX: 9 1 - 5 3 ~ 4 6 7 . , 91-4410136,91-4410137 Mumbai - 400 085. FAX: 022- 55565t3

J I. The Director ([ceh),

Power Trading Coqin. of India Liituted,-

.::nd Floor, NBCC Tower, ..

I5B~;Carna Place, }!ewDelhi-l-Hl0660 ... .... -FAX-611-51659504

Sir,

.Sub: Sixteenth meeting of the Standing Committee on Power System Planning in SoUthern~ e g i o n . .

Enclosed please fmd siurunary record of discussions in tr.. 16'" meeting of the Standing COllunittee on

Power System Planning in Southern Region held at Kaiga on: 20'" January 2003.

Kindly aC!<nowle<:\ge the receipt.

Encl: As above.

•

Yours faithfully,

~ ~ ~ ~ . r : : ' )(AX Asthana)

Director (SP & PA)

Annexure-IV

Page 14 of 34


~'::':::;:C:2:~y .. ;··:..c'~;,,-d·';\if ~;';~iZ';;ii,~ii5 ill (ltc' lS~ meeting of' .'I.e L:;)(AUU.....g

Committee'on Power System Planning in Southern Region,held at Knigs on20

th.Januarv 2003. -

,!

p.'.". . .... -;;.,'

#'1".t>'

..-

List of participants is enclosed at Annex-I.

Station Director, Kaiga APP Generation Station, NPCIL welcomed the participants and

gave a presentation on the achievements and future programme ofnuclear generation capacityaddition by NPCIL. He also mentioned tb.e difficulties that were being faced by the Kaiga APP

on account of grid operational problems and the need of improving the maintenance ofprotection system at Hubli substation of KPTCL.

.Chief Engineer (SP&PA)" CEA welcomed all the participants to the 16Ch Standing ~conunittee aria thankedNPCU: foi-a;:rnngiiig-the meeting at-Y.mga APP and- for making

excellent arrangements. He requested Director(Transmission), KPTCL to look into the

problems of operational coordination between Kaiga APP and KPTCL substations and

protection system at Hubli. Director(Transmission), KPTCL agr<;ed to, look into the matter andassured that whatever was necessary, would be done.

111e agenda i t ~ q t $ ,were thereafter takeD up for discussion.

1. Confirmation of Sumrna,ry record of disI'ussions of the 15'h Standing ConunitteeMeeting•.

rhi"'f Engineer (SP&!'A), CEA stated that the sununaiy record of the 15'h meeting held

on 18-4-02 at Bangalore were circulated vide No.5114ISP&PA-2002/184-97 dt. 24-4

2002 and no observations or objections have been received from an)' participant.

, Thereafter, the summary record was taken as confirmed.

- - - ~ ? ~ Review of progress.on tile deasiens talrea in t ! t e - - U j ~ - - c i i o g .

2.1 Provision ofnew 400kV sub-stations and additionaltransfomlers at existing s/stn.

Chief Engineer (SP&PA), CEAstated that' based on discussion in the last meeting,

proposal for new 400kV substations and additional transformers at existing substations

under regional scheme, had been considered and it was proposed to include the

necessary provisions under !the R.;gion::! T!'3l1Sm;s";onJ~ystem for Kaiga Extension

(Unit-3 & Unit-4. 2 x 235 MW) and Neyvel1 TS-II Expansion (2 x 250 MW) Projects,

covered under agenda item-5.,

2.2 Kaiga Stage-l..Transmissioll System,- UpgradiIig Kaiga-Sirsi-Davanagere line for400kVoperation' . ' ,

The progress "of works f0iupgraded operation ofKaiga+1>avliiiagere line,to 400kV was

revieWed. NJ'cn, intimated that the w-otk at Kaiga end woulQbe ready' by December2003.

In reg;rrd 'to works at Davanagere end, Director ( T r a n s ~ i o n ) , KPTCL infonned thattenders had was already been irivited. The teclu1ical bids bad been opened and the cost "

Annexure-IV

Page 15 of 34


bids were to be opened shortly. Howe..::r, before KPTCL proceeded further, decision

on the cost sharing of the Sirsi-Davanagere section ofthe line was required.

The issue was discussed and it was noted that 'the Sirsi-Davanagere section of line of

KPTCL would become an integral part of Kaiga-Davanagere 400kV D/C line. Also,

there would not be any 400kV switching station at-SirsL As such, the Sirsi-Davanagere

section of 400kV Kaiga-Davanagere D/C line as well as the two 400kV line bays lhat

were required to be provided by KPTCL would qualify to be a part ofregionaJ systemin all respect.

In view of this, it was agreed to include the Sirsi-Davanagere line section and the two400kV bays at Davanagere under the regional scheme and it was decided that M S ~

SREB would take-up t 1 J i ~ issue for getting this endorsed in_f!t~SREB forum. Howeyes! ! J j ~ W h ! 1 . I r l . h e treated as a 3pecific case and not linked the proposal for tranSfer ofother

transnUssion system of State utilities under the Regional category that was beingdiscussed Beparately in the SREB. ..

It was also decided that KPTCL would go ahead wilh lhe works for provision of bays at

Davanagere end and not wait for lhe SREB process. .

2.3 ULO of second circuit betWeen Kadra and Kodasalli at Kaiga.

._--_._.- ~

CE {SP&PA);CEA stated that the \ ~ e w s of NPCIL and KPTCL forwarded to CEA on

the LILO proposal were examined and. as this was more of an operational issue, thematter should be shorted out by KPTCL and NPCIL between them or in the OperatingCommittee ofSREB.

2.4 Kaiga-Narendra 400kV D/C Line and Narendra 400kV Substation

POWERGRlD representative intimated that the forest clearance for constn.tetion of

Kaiga-Narendra 400kV line had finally been obtained in November 2002. Forcstablislunem of Narendra 400kV SIS they were .in process o( preparinj( FR for

obtaining approval of their Board. The construction schedule of400kV Kaiga-Narendraline along with Narendra 400kV SIS was being programmed for completion and

-'--'------~CO~[-m-9~ssio!1ing by Mm:ch 2005;'

In regard to commissioning of Kaiga Sig-U, NPCIL informed that civil' constructionworks for Kaiga Stg-II project was aoing on' at rapids pace and.the project was

. p'resently scheduled for cominissioning by December 2006. .'

3. Co-opt of PTC as a member of standing Committee.

CE(SP&PA) stated that the PTC Was a facilitator for trading of power to beoeficialy

states of different regions .The role of PTe was significant considerlng the power

deficit in Southern Region and possibilities,of meeting the gap through supplj ofpower

from other regions esperla!!}' from the swpius .I!vailable in Eastem Region. PTC was ina better position to provide information regarding emerging power excllange modalities

and availability ofpower from future generatJng stations enabling decision for pun:base .

ofpower judiciously. He requested the members to give their views on the proposal. . .

- ..,.

Annexure-IV

Page 16 of 34


·' r-

.:' .. -

"

'~<:,::'l\1:

, Director, PTC" an special invitee to the'meeting, elaborated upon the role being playedb ~ prC in the power trading.

Director (Trans), APlRANSCO and Director (Trans), KP,TCL wanted to know whether

PTC would be i D \ ~ t e d as special invitee or as a member of the committee and whatwould be its role in the process ofagreement or decision on the issues,

CE(SP&PA), CEA stated that it was proposed to co-opt PTC as a member df the

committee, He further explained that the decisions in the Standing COnullittee were

arrived on the basis on consensus among those members of the Standing Corrm.1;tlee

who were the affected parties for the particular issue. As such, the role of PTC wouldbe more towards providing information and in participative discussions on issues, and

not in decisions relating to regional' t r a l ' : c W . m : ~ " l o ' 7 , ~ . ; ; 0 ' ~ : ; 0 " - : " - ; ; . I l - 2 l ; : : ' - - " i k . " , - , ---

After discussions all the other members of the Committee unanimously agreed forinduction ofPTC as a member ofthe StandingCommittee ofthe Southern Region,

4. National Grid for Southern Region:

, '---,.---Inter-regional transmission system for i m p o l j _ o S ~ " - l ! . i . ! ! o ! ! " ' " power by the Southern

, Region from operational surplUses in Eastern and other regions and providing allIndia connecthity:

Chief Engineer (SP&PA), CEA stated that manv thermal power projects in Eastern

Region like Kahalgaon EA'fension, Bam, Maithon RBC, North Karanpura, etc were being'

envisaged to come up during the 10th and 11th Plan periods and generation from theseplants would be transported ta neighboring delicit regions. Formation of National Grid

connecting Eastern Region with the Northern Region and Western Region was beingenvisaged in this conteAt With Rourkela-Raipur inter-connection, the Western Region and

by year 2005 the ,Eastern ~gion would-start o ~ r a t i n g in synchronous mode very shortly,

Subsequently, with ,Tala transmission system, the Northern Regi()fi and Eastern Region

',,'. _"" vv0uld also get"-inter-connected synchronously. North Eastern Region \iias alreadyopetating with syn<:hronous, AC inter-eomection' "lith. Ilastem Regioo. With-this,· all

regions except the Southern Region would be in synchronous operation. With

strengthening ofNational Grid network associatedwithBmh and Kahalgaon etc., the !otal

netWork'of ER, NER, WR and NR would operated as an integrated system.' It was

•.proposed to extend the National Grid to the Southern region also so that an all Indiaintegrated grid could be realized. :

Director (SP&PA). CEA gave a presentation on the propositI of extensioh ofthe National

Grid for Southern Region (enclosed at Apperidx-l). The presentation highlighted that with

the demand prdjection as per 16th EPSand generation programme that was being

envisaged, the. Southern Region would n ~ an ad.ditional tie-up for 2000 t03000 MW for

meeting the full supply requirements by'200S-G9. This would be in addition ::1 Su::,p!yfromTaicher-II, 2000 MWand imports ofabout 1000 MW viaGazuwakaHVDC b a c k - ~ o back Iink.. Further, as the current trends ofdemand growth in.c3se of the Southern region

were higher 1JJan the 16 EPS projectiODS. the requirement ofadditional tie-up could be still

higher if the demand groWth in Southern region continued as p e r ~ : } current trend. A cost

effective ' p o ~ i b i l i t y for meeting this demand would be' thrOugh ilIlJX'rt from Eastern

Region. For enabling this import and providing all India inter-connectivity, it was

proposed to i n ~ [ u d e the Southem region also under the ambit of National Grid by

- - - ~ -

Annexure-IV

Page 17 of 34


,<(

. .....~

~tendjnlt fhe 76~kV network ~ p to Raichur. S~dies to evolve the r ~ u i r e d s y s t e m ~ «oeen earned out m eEA and C1rculll!ed along With the agenda A reView of the optio

considered, results of the studies and an iJ)dicative cost comparison of the alternativ. 4were also presented (please refer to Appendix-l for details).lndicative cost for option-l,AC \

Altem~tive was Rs.3200 crores,for option-2,Hybrid Alternative was Rl;.5000 crores antE ~Cfor optlon-3, HVDC Alternative was Rs.5800 crores. . . ,

(

'(

The members generally agreed to the need ofNational Grid connectivity for the South"m

Region.Ofth" 3' alternatives, the choice was generally between A1t-l and A1t-II.'-.

Dilector (fransmission), KPTCL asked regarding adoptability of 765 kV transmission

system and the cost difference \!e.tween 400kV Quad 'conductor lines and 765kV lines.

q t i ~ . g i n e e r (flJ'M'.t\J, tEA r . 1 . " J ; i . ( i . " , ! , ~ ~ ? , q 6 S ! - , ' f , ' ' ! ' J l b , , ' ' e - w J c l . . t > . l l l r b e e n well acceptedlevel as'next higher tran]rnission voltage. As compared to 400kV D/C Quad conductor

line, the cost of765kV SIC line was less as it had only 12. conductors against 24 in case ofthe former. However, iii case of765kV, the cost of substation equipments was higher. On

over all basis the two were more or less at the same level of cost. The t"vo were alsocomparable in respect of thermal limit of transmission capacity. However, the main

advantage of 765kV level was due to its high SIL, which enables 765kV system to providehigher transmission <::.pacity over longer distance with stability.

ED (Engg.), POWERGRID-suggested--that' . National Grid formatiQn and integrated

operation of regions should be implemented in a phased manner. He further stated that

though AC 'option worked' out to be economical it would be prudent to go for Hybridsystem for SR National Grid for operational considerations.

Director, APTRANSCO emphasized. that priorities should be given to security andreliability aspects towards formation of the SR National grid and stated that HybridSystem, though it appears to be a little costlier, could be envisaged. '

Me~ber (Teclmical), KSEB stated that after Talcher-Kolar HYDe bi-pole link was fully

realized, it would be preferable to go for option-l for fonnation of Southern National

Grid. He suggested that pl.anni;1gof Southern NatiornlI Gridsnould be made in stages for

s ~ o r t and lor'l> ,t:ll11 basis. CE, TNE!3 ~~rted the views o~.I<S,~E:...B..:.. ~ _

. CE (SP&PA), CEA suggested that all the constituents could again go iliroughthe studies

circulated along ~ ageII!1a in light of the presentation and <jiscusSiOIlS' durihgthemeeting and sent their. suggestions to,CEA by the end of Feb11lllIY2003. Based on tf:.e

.. inputs, CEA would cany out further studies to finn up the prQPosal and the same could bediscussed and finalized in the next meeting. '. '.

" ... _..

".,

5. Review of the proposal forLILO of400kV Gazuwaka-Vijaywada D/Cline at,Vemagiri ~ . . Q d Signing BPTA for implementation of 400kV Rourlrela-Riapur-Ouuldrapur scheme . .'., ,

. CbiefEngineer(SP&PA) stated that thb:LlLO'ofGazuwaka-Vijaywada400kV ri/C line

afVijaywada was agreed to in 1Ile "lSCh'iheeiing of the.standing committee meetings

subject to completion of Vemagiri-Tl1(Jiko\1d8:400: kV DIG Iines by APTRANSCO.

~ w e v e r , in view of APTRANSCO 'and':rNEB not agreeing for sharing of tlle

Rourkela-Riapur-dandrapur 400kV systernevolved as a falI.-back transmission systemfor Talcher-U' and agreed in the 12th meeting of t/:!e standing committee, the

Annexure-IV

Page 18 of 34


j

,,

6.

..•.•c .. " - " " ' ~ ' - ...... .•._.

implementation offullback system for Talcher-II has been.held up. The need for reView

of Vemagiri LILO proposal had been felt in this context. In a meeting taken by

Chairman, CEA with the SR constituents on the issue of signing BPTA for

implementation of 400kV Rollrlrela-Riapur-ebanem.pur scheme, APTRANSCO

representative had stated that. instead of sharing transmission c!JaJl:es for the suggested

fall back System, they would prefer.to cany out load shedding. With application of this

planning criterialphilQSopby, the need for LILO of Gazuwaka-Vgaywada at Vemagiri,

which was also a full back arrangement for meeting the contingency of outage 0 r .Vemagiri-Tadikondaline, was also argtiable.

The issue was discussed in detail. KPTCL informed that they have already conveyedtheir agreement for the 400kV Rourkela-Raipur-ehanem.pur DlC line. CE (SP&PA).

C E A m ' . p h ~ <he w~y of sigtling the BPTA for the RoUrkera=RiapurChandrapur scheme so that full back system· could be put in place. Director

(Transmission), APlRANSCO requested CEA to forward a consolidated note on theissue so that the matter could betaken up for a review in his organization. CE

(SP&PA), CEA stated that all the necessary information was already available With

APTRANSCO in their record. Ho\V<,;ver, he agreed to send a note covering background

on the issue and justification details for taking uP the scheme so as to facilitate thereview process by APTRANSCO and l N E B ~ ( a n d also by. KSEB, KPTCL and

Pondichery for e x p e d i t i n ¥ ~ ~ g n i n g o f B ~ ~ A).

Additional Transmission system for Kaiga APP Stage-II (3A1 and 4

thUnits), and

Evacuation system (or Neyve.li 1'8.11 Expan~io" Project (2x256 MW).

CE(SP&PA) stated that upgrading and operation of the existing Kaiga-sirsi

Davanagere Ole; line at 400kV level and adding Kaiga-Narendm400kV D/C line aspan of approved Kaiga. evacuatron system would not be sufficient to meet stringent

requirements for the Nuclear Stations. Also, with addition of2x235 MW underStage-IIof Kai"a, taking total capacity at Kaiga to 910 MW, additional transmission lines from

Narendra were needed fur dispersal power towards Devanagere aDd from thereon to)

load centers in South Karnataka and North Kerala. He further stated that Neyveli T8.U

Exp<l!lSion pr~jeet· (2x259MWr was also eoming-m-the'region in the sarne-tiUte f.mIre

and transmission System the same md also to be evolved. Accordingly,CEA had. earned out studies for evolving the required' transmission ~ The £eSl!.It of the

studies and the proposal.system had been circldated with the ageildaThis was requiredto be discussed to finalise the tranSmission system. . .

..,

Thereafter, the proposal as <:ODtl\ined in· the agenda n;te was discussed in detail and

based on the technicai need"of system strengthening for evacuation and dispersal of

power from the extenSion projects and also for taking care ofrequirementsaiSingout·

of changes in flo,w pattern on accountofgrowth ltldemand and ffldistributionofpower .flows, the following decisions ~ t a k ~ . . _ -'. ,. .

(a) It was agreed that in addition to new 400kV s u b s t a i i o n s ' W i t h 2 X 3 1 S f ~ V A ~ ~ .•

. .at Mysore (I<arnatl!ka), Kozhikode (KeraIa),Pondichery and P u g a 1 u r ' ~ ~ ; : . ,second 315 MvA transformer at Yijaywada as proposed in t h e a g e r u l a , ; 8 d ~ ~ ' :400kV sUbstations With 2x315MVA capacity atWarangaI (AP.) and Melakottaiyur

(mEB) were also needed arid it was decided to include these under the regionalscheme. . .

Annexure-IV

Page 19 of 34


(b) The need for ' . ) n ~ additional .H5 MVA 4O<J/220 kV additional transfonner each a t ~ " '..

Davanagere substation ofKPTCL (2"" transformer) and Trissur substation of KSEB ,

(3'dlransfonner) was also noted. However, as Davanagere and Trissur were already .

existing substations of KPTCL and KSEB respectively, the additional transfonners ' \ ~

would be provided by the respective utilities owing the s t ~ b s t a t i o n s at their own cost .

and compensatory provision under the regional scheme would be covered in some : tfuture scheme.

(c) KPTCL suggested that 400kV substations proposed at Haveri could be deleted ~ dinstead, second 315 MYA transformers at Hiriyur could be provided. This wasagreed~

(d) In regard to the suitability oftaking line to Mysore from Somanhalli via-a-vis from

Neelamangala 400kV S/Ss, KPTCL stated that Neelamangala would be better P0int

to take-<!!f the line from SYSlem and ROW consideration: AcCordingly, it was

li6cided to have the line from Neelamangala.

(e) Taking note of result of studies for evolving e"acuation system for Kudankularn.

which were circulated as a supplementary agenda, it was decided that instead of

taking towards Trichy or Udumalpettai, the 400kV line from Neyveli to Pugalur

would be extended towards Mudrai.

(0 TNEB suggested that 400kV substation proposed at Villupuram could be deleted

and instead, 400kV substation at Arasur could be provided. ·This was agreed. It was

also decided that instead of LILO of Salem-Udumalpet as was proposed'earlier by'

TNEB,. the interconne..--ting arrangement for Arasur substation would. be 400kV

Udumalpet-Arasur D/C line, because this would fit better in the perspectivescenario.

(g) On suggestion of POWEGRlD, KPTCL and TNEB, it was agreed that the 400kV

lines thai were proposed to be SIC would be revised. to DIG. Though this would

result in lower initial utilization, this decision was taken \vith a view to reduce

multiplicity of lines in long run and save ROW.

Accordingly, it was decided that the following works would be covered under the

regional transmission schemes for Kaiga-Il and Neyveli-II Il.:P. systems:

Kaiga-II Transmission System:. (1) Narendra-Davanagere 400kV ole

- ~ - - - - ~ ( 2 ~ ) ~ - - - N e c l a m a n g i i I a - M ) i Q r e - c 4 " ' O " ' O " k V " ' D ' I ' ; ' C " - - - - - - - - - -

(3) Mysore-Kozhikode 400kV DIe(4) LILO (lxD/C) of 400kV Kolar-S P Budur line at Melakottaiyur'

(5) New 400/220kV,2x315MVA substations at Mysore, Kozhikode andMelakottaiyur •

(6) SIS extn for line bays at Narendra, Davanagere and Neelamangala

(7) Second 40nr22'JkV,315MVA transfonner at Vijayawadaand Hi:iyur

Neyveli TS-Stil Expansion Transmission system:(1) .' Neyveli T8--II Expansion-Neyveli TS-ll 400kV 2xS/C

(2) Neyveli TS-II Expn.-Pugalur 400kV D/C .

(3) Pugalur-Madurai 400kV D/C .

(4) Udumalpet-Arasur400kV D/C .

(5) LILO (IxD/C) ofNeyveli-S.P.Budur 400kV SIC at Pondicbeny

(6) . LILO (lxD/C) ofRamagundam-Khanunan'l. 400kYSIC at Warangal

.(7) New 40&1220kV, 2x315MVA substations at Pugaiur, A.rasur, Pondicherry

and Warangal .(8) SIS Extn for line bays at Midurai and Udumalpet .

Annexure-IV

Page 20 of 34


Anil-CTU

Rectangle

)'

;

7.

Early scheduling ofworks:

Director (Transmission), KPTCL informed that KPTCL had desired to construct

Neelamangala-Mysore 400kV D/C line ab::g with Mysore 400kV substation (part of

regional transmission works under Kaiga Stage-II) ahe.,d of the commissioning of the

generation units so as to facilit3te supply to Mysore area for which full transmission

charge was proposed to be borne by KPTCL till commissioning of the first generating

unit (U#3 or 4) at Kaiga APP. Member, KSEB and Chief Engineer, 1NEB made

similar suggestions in respect of Kozhikode and Melakottaiyur substations. It was

agreed that the respective utilities mighnake up with POWERGRID for needful.

Construction of Raichur-Gooty400kV DIC line instead of eatiier ag'-eed proposal

for LILO ofHyderabad- Kumool400kV SIC line (part orlWnagund>m:.m"'",mi";On')-.tcrn) atRaichur.

·'

CE (SP&PA) stated lhal based on route ~ ' l f v e y , POWERGRID had infonned that LlLO

of Hyderabad-Kumool line at Raichur, ~;cluch was decided in the 12th

meeting. would

involve construction of a 400kV D/C line ofabout 95-J,.-m leng!h, which was quite long.

----In.view_ofthis, there was a need to review the proposal and it was proposed that insteadof the LILO, a 400kV D/C line from Raichur to 'GOoty-as-,vas'suggested by KPTCL

earlier, coulq be considered. The Raichur-Gooty line "las also found to fit well into the

plan of National Grid for Southern Region, presentation on which was made during themeeting. Director (SP&PA), CEA stated that as per the studies for National Grid for

.Southern region, the requirement of 400kV Raichur-Gooty D/C line with QUAD

conductor was found under the AC and Hybrid alternatives. The proposal was then

discussed in light of presentation on National Grid for Southern region and it was

agreed to include the construction ofthe line Wlder the regional strengthening scheme.

8. . LILO ofNeUore-SripenurJmdurline at Alamathi SIS ofTNEB.

". ~:.:::.-rE (SP&PA) simes! iliaf b a s ~ . . r o u t e survey, POWERCdHO badjnfonned that the

route length for LILO of Nel1ore-S.P.Budur line at Alama1hi was coming out to beabout 85-90 kIn and therefore, they had proposed that instead of LILOof both c_ircuits,

as was agreed earlier in the 12th meeting, which would require 2xD/C.lines, only one"circuit couldbe LILOed. .

ED, POWERGRID stated that as per the studies carried out by them, LlLO ofonly one

circuits was also found to suffice the pwpose ofproviding the required connectivity for

Alarnathi: -,

CE,TNEB stated that the route 1en8th for the LILO would only be ofihe order of55 kInand as such Lll..O ofboth ci.."Cuits ai already agreed should pe retainecJ:

CE (SP&PA). CEA stated that ifthe load requiremeills could besatisfuctorily met withLILOof only one circuit, one circuit Lll..O may be taken up in first phase and ifneed

be, t h e . ~ e & > n d circuit could be I..ILOed at a later dale.

Annexure-IV

Page 21 of 34


9. Execution of LILO/b:oy eJ:tcnsiOil works at Mehboobnagar SIS ofA?TRANSCO

tor LILO of Nagarjunasagar-Raichur 400kV SIC line and. LlLO/bay extension

works at AJamathi SIS ofTNE"B for LILO ofNellore-Sriperumbudur 400kV line.

CE (SP&PA) stated that confirmation was requir:--c from APTRANSCO and TNEB

about their position with respect to the execution arrangement for the bay extension

works at Mehboobnagar SIS and Alamathi SIS, LILOes which were decided in the 12th

meeting. The bays at their respective substations were required to be executed by them

as.. part of regional scheme at the cost of POWERGRlD. Director (Transmission),

APTRANSCO and Chief Engineer, TNEB confirmed their agreement to the proposed

a r r ~ . . 8 e m e n l . _ I t was clarified that POWERGRID wodd pay the respective cost and

,eeover transmission charges as part of regional transmission system. All the members.took nole of this.

--;;---

~ ~ ~

t " i ~ ~

10. Evacuation arrangement for Kudankulam APP Stage-I (2x1000MW)'<

Director (SP&PA), CEA stated that Kudanktilam APP Stage-I (2xIOOOMW) was plannedfor commissioning at the start of II th Plan, that is first unit in 2007-08 and the second unit

in 2008-09. The transmission system tor e . ~ I l _ ~ 9 . ! ! ! L O f powC!" from Kudankulam was____required to be evolved and finalized so .tIiat it could be programmed for commissioning

matching with· generation programme. Though the shares of the beneficiaries of

KudankuIam were yet to be finalized, transmission requirements for evacuation of powerfrom the project could be evolved as actual delivery of power would be through

displacement, and Kudan1:ulam being located at an exireme end, the transmission systemwould be practically independent of share allocation from generation. In this context, CEA

had carried out studies and the results of the studies along with proposed evacuationnetwork was circulated as a supplementary agenda. The following system \:as proposed:

FOR EVACUATION

o LILO (2xDIC) of both circuits of Madurai-lbiruvananthapuflWl 400 kV ole Ii,at Kudankulam. _.-:--_--'- ,

• Kudankulam-TItiruvanan!hapurw-Pailom-Trissur400 kV D/C Quad line

• New 2x31S MVA 400kV substation at Pallom ..

..• Third.31S MYA transformer at Thiruvanan!hapuram,..

FOR START-UP POWER

o Tuticorin-Kudan1.'U1am.220kV SIC Zebra conductor

o Thiruvananthapurw-Kudankulam 220 kV SIC Zebra conductor, ifROW permits

else, Kayathar-Kudankulam 220kV SIC Zebra concuctor

':' ~.

ED (Erigg.), POWERGRID stated that getting ROW i:1Kerala was v&y difficult a n ~suggested that Kayathar substation in Tamil Naduwhich'Was en-rouW to Madural

Thiruvananthapumm line could be abetter point forKAPP evacuation, POWERGRID

also circulated a new proposal during the meeting.,

Annexure-IV

Page 22 of 34


Member, KSEB slated that they could provide ROW for. establishment of 400 kV lines

under Central Sector by dismantling ofunIoaded 220.tV and do\Ynward transmission linesin their system

ED (Engg.), POWERGRlD s u g g e s ! ~ that a joint survey by CEA, POWERGRID and

KSEB would require to be carried out to find the availability of ROW/Corridors in Kemla

before finning oftrans'uj""ion system for KAPP projects. 1lle same was agreed and It was

decided that the programme ofjoint survey would be finalized separately. ..

GM,NTPC s t ~ t e d that NTPC \vas proposing e.,tension ·project at Kayamkul:un and it

would be desirable that the evacuation from this project may be examil.ed along \\ithKudankulam p r o j ~ t . .

Based on t\1e above discussions, it was decided that evacuation and start-up power system

for KAPP would be reviewed based on outcome ofjoint route survey and further reyiew

studies to be carried out considering Kayamlmlam E"in. Project.

".--,

II. Summary of decisions:". :'

o KPTCL to look into the problems of operational coordination betweelLKaiga

API' and KPTCL substations ~ d p:?tection system at Hubli.

• Summary record of discussions of the 15th Standing Committee Meeting as

circulated \ ~ d e No.51/4/SP&PA-20021184-97 dt. 24-4-2002 were confirmed.

• The Sirsi-Davanagere section of 400kV Kaiga-Davanagere D/C line as well as

the two 400kV line bays that were required to be provided by KPTCL at their

Davanagere substation "'ould qualitY to be a part of regional system in allrespect.

oMS, SREB would take-up (or getting this endorsed in. the SREB forum.

However, this would be treated as a specific case and not linked the proposal for

transfer of other transmission system of Slate utilities under tIle Regional"category that ,vas-being discussed sepmateiy ill die SREB:' _.n ----

o KPTCL would go .ahead with the worlcs for provision of bll)'S at Davanagere

end and not wait for the SREB process and schedule oomniissioning to match.

with o o r n r n i s ~ i o n i n g 400kV SIS at Kaiga ~ presently for Dec, 2003.

• pTC was co-opted as a me:nber ofStanding Committee. .

o All the constituents would again go through the proposal for National Grid for

Southem Region and the studiesdrculated along with agenda in light of the.

_ presentation and discussions during1he meeting 1lIld sent theit suggestions to

CEA by the end of Febniacy 2003. Based on the inputs, CEA would can)' .out

- further studies to ficm up the proposal and the same could, be discussed andfinalized in the next meeting. . .

.. CEA Would circulate a note covering background-on the issue and justification

details for taking up the scheme so as to facilitate t.J,.e review process by

Annexure-IV

Page 23 of 34


., c;;

c...~

<;;

~

,il

~

'itNarendra-Davanagere 400kV DIC

Neelamangala-Mysore 400kV DIC 'itMysore-Kozhikode 400kV DIC

LlLO (IxD/C) of 400kV Kolar-S P Budur line at Melakoltaiyur 'iNew 400/220kV,2x315MVA substations at Mysore, Kozhikode<md...__ ....·•. r:

Melakottaiyur . . . !Of

6. SIS a1n for line bays at Narendra, Davanagere and Neelamangala <;;7. Second 400/220kV,315MVA trailsfonner at Vijayawada and Hiriyur

'- ,,~

I. Neyveli TS-I£ El>1lansion-NeY\'eli TS-II 400kV 2xS/C

2. Neyveli TS-Il Expn.-Pugalur400kV DIC

3. Pugaiur-MaduraL400kV DIC

4. Udumalpet-Arnsur 400kV DIC

5. LILO (lxD/C) ofNeyveli-S.P.Budur 400kV SIC at Pondicherry

6. LILO (lxD/C) ofRamagundam-Khammam 400kV SIC at W.rangal

7. New 400/220kV, 2x315MVA substations at Pugalur, Arasur,

Pondicheny and Warangal8. SIS ElI.1n for line bays at Madurai and Udumalpet

I.2.

3.

4...5.

APTRANSCO aad TNEB (ami also bYKSEB;KPTCI:. &lid Pondichery forexpediting signing ofBPTA).

Kaiga-II Transmission System:

Neyveli TS-St.1I Expansion Transmission system:

• The following works would be covered under the regional transmission schemes

for Kaiga-1I and Neyveli-II Exp. systems:

o For early scheduling of works, with the arrangement that requesting state utilitywould be beari.itg full transmission charges till transfer of assets ur.der regi,)nal

.__-,-__ ~ _ ~ \ \ ~ ' o ~ r k s ~ , . ! ' ; t h ! , , : e : . . : r ~ p " e c t i v e utilities !Uig!1t take up with POWERGRlD for nee4fuL

~ lnstead of LILO of Hyuerabad-Kumool line at Raichw-, (which was decided in >-....)..the 12

1h

meeting), Raichilr-Gooty400kV ole line with QUAD conductor ",ould \

be taken up for construction under the regional strengthening scheme.

• In view of longer route length, instead of L1LO' of both c i ~ u i t s of Nellore

S.P.Budur line at Alamathi as agreed earlier, LlLO of only one circuits would

suffice the purpose of providing the required connectivity for taking up in first

phase and, ifneed be, the second circuit could be LlLOed at a later date.

• Ajoint survey by CEA., POWERGRID and KSEB would be carried out to find

the availability of ROW/Corridors;in Keraia and the proposal for evacuation

and start-up power system for KudankuJam APP would be reviewed based

on outcome ofjoint route survey and further studies considering ExIn. Project atKayamI..'U!am.

,

Annexure-IV

Page 24 of 34


r ·/.

.,". ., ANNEXURE-I

List ofParticipants

The following Officers participated in the 16~h Standing Committee Meeting on 'Power System

PlaIUling in Southern RegIOn held on 20';' January,2003 at Kaiga NPCIL.

.'

t

')

Name

Central Elech;city Authority

1. ShrfV.P..a,.T-~!~~-;k.r:f..--·-··'

2. Shri A.K.Asthana3. Shri R.Saha

S.R.E.B.

I. Shri S.Sivan2. Shri A.K.Yadav

POWERGRID

I. Slui R.N. Nayak2. 8lui V.Lak.shmpathi3. Slui Y.K.Sehgal4, Slui Pankaj Kumar5. Shri Babu Varghese6. Shri A.Chockalingam

7. Shri C.N.Suresh Babu

.....N.I.P·L..

I. Shri N,N.Misra

N.P.C.I.L.

I. Shri K.J..Sebastian2. Shri G. Nageswararao,3. Shri V.Ka!lSUmU4. Shri RC.Sinha5. ShriK.Rainamurthy,

6. Shri C.S.MaIipatil7,_ 8hri Rajesh Laad8.

9. Shri R V.Manohar

~

I. Slui S.K.Dube

Designation

ChkfEng'u"lcer (SP&PA)

DirectorDy. Director

Member Secretary

A.E.E.

Executive Director(Engg.)Add,!. Gen. Manager

D.G.M.D.G.M.D.G.M.Chief ManagerCl-Jcf Manager

--......,....~---_. ._.

G.M.(Elect)

Director(fraris.)Station Director(KGS)

I>irector(E&P)ProjectDirector

CE(KGS 1&2) ./CE(E&P)

DGM(frans.)

SOl(fV)

' - . ~

Director

Annexure-IV

Page 25 of 34


1. Shri G. Kesav Rao

2. Shri M.Sitarama Sarma

I. Shri S.Shivamallu

2. Shri S.K.Sridhara

3. Shri S.Ramesh

4. Shri Syed Zubair Ahruned

5. Shri P.L.t-.fanjunath

6.. Sbrirs.B.~hX'l!1lan

7. Shri S.M.Mudeshwar

T.N.E.B.

I. Shri M.Durair:Y

Nevveli Lignite Corpu.

'1:"SOO S.Rajaram

KS.E.B.

I. Shri C.Abdulla

,

,

Director(frans. & GO)

SE(fech. & SS)

Director(frans)

EE(Planning)

E.E.(Corp. 011)

AsstLEx.Engr. (Corp. off)

. Asstt.Ex.Engineer (Planning)

, ~ ( E l e c t . )

.Section'dfficer(Kadra)

Chief Engineer(Pig.)

Add!. Chief Engineer

Member(Trans.)

'c;.;

~

c;~

~.~

~li;i

~

(iI;;

-

\.'

~

{ ,"

{

(

(

(

Annexure-IV

Page 26 of 34


, "

·iI..

Aff&.rlj!rx -.z

• "1

j}j,jjJjfJ@1iff!~. flJiD

Demand and Generation Capacity Projections

Power Supply Scenario 2008-09

Import Needed by SR

Further Import Possibilities

National Grid for Southern Region

Indicative Estimates and Transmission Charges

Pro·ected Demand and•,Anticipated Generation Capacity

'. "

Annexure-IV

Page 27 of 34


.r F - ,

Power Su I Scenario 2008-09

.Availability within the region and need for import -- 2008-09...... ... . MW'

'PeakdemaOd 16EPS 35035.:!iYiiiO Cap3cijy . i2322

ThOnnalcapacijy 30590

Tola'.. _...--..... ~"" __.'-_ft-/..~{!c=!!:~'1 :"'.:;<;;O,3S% Demand Need of

'Scenario- Hydro % Thennal % MW of peak MW import, .

HIGH HYDRO

Peak hrs 100 65 32200 100 35000 280{)."-_..... ~ f f ~ e . a . k h r s 70 60 27000 80 2800{) 1000

lOW HYDRO

. Peak hrs 40 75 27900 100 35000 7100

, <If.I~eakhrs 10 75 24200 80 28000 J80{)-_._.,-------"- .

1m art Needed b SR

\

2

Annexure-IV

Page 28 of 34


Further Import Possibilities

Orissa

SRrnay seek import from ER

500

300

-500.

500

500400;

500:500!

500

4200:

iDVC

'NHPC Teesta -v

Teesta LD & Teesta HD'

Chandrapura extn .

Mejia extn

iWest Bertgal Sagardigh'

Bakreshwar extn.

Balagarh

Dubri

IB extn

) ~

,

1

REFER TO AutoCAD ': SR system

./" ..... -.~--:::.-;: ...

T·-:~~ .

,

. 1 \-- .-

),

)

Niltionill Grid for Southern Region

~ National Grid.... SYI1c;<.l1roflOus connection -g7'iv-,i-n-g-,b-e--:tt:-:-e-r-------J---·-

stability and improved f r e q u ~ n c y ~ ~reguJation . ~

I» All India connectivity enabling optimum

dispatch and trading

~ Transmission CorridorslH Gazuwaka

.... Talcl1e"r-Kolar

I» Rourkela-Raipur-Ghandrapur

1»' Balia-Daltonganj-Sipat-Seoni

-Wardha-ParJi-Raichur

Annexure-IV

Page 29 of 34


<:J{J(JtJ~tJf ~UV<t:JI.si\jVtiVV"-'

FORSOUTHERN~~ION .

jl:

,:{

'r."

..

,p

"{:

v.. 'llV

....';:

I

. II

,,

~

,

';

'WR/NR/ER lines

. SR 50Y.

SR IOOY.

LEGEND

RClnchl

Tenugho.t

HVDC ~"~765 kV _

400 kV DC :

400 kV SC '--

"

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Annexure-IV

Page 30 of 34


l~AUU ... y... t7lfY .FOR SOUTHERN W3.loN : I

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. HYBIRD OPTION \

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SR 50'<

SR 100;1,

LEGEND

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HVDe --1"111--765 kV --

400 kV DC ==400 kV SC --,-

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Annexure-IV

Page 31 of 34


• ~,~ ~. ~ ~ (-~~ v ~ ~ v v v ~ w ~. v v ~ v u v u V V U v ~ ~

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Annexure-IV

Page 32 of 34


~r"".;.: " .

.;- .,: i

/ ,

II

stimates an ransmission arges

National Grid for South~rnRegiDn

51

79

92

50

3000

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o

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_ . ~ < : : O p t ~ . ' : .._3_20.0__ .... 1000

Hybrid Option 5000 1000

HVDe Option 5800 1000

Talcher.-II Tr. 3400 2000

System

""'fA-.,..-v>"..-v:v:Yl'fY.'il'Y.Yn11umdO.

4

Annexure-IV

Page 33 of 34


Annexure-IV

Page 34 of 34


/.

SUMMARY RECORD OF 9TII M.EETING OF THE. SlNiDING COMMITTEE ON MATTERS RELATING TO

. POWER SYSTEM PLANNING IN SOUTRERN REGION.HELD AT THIRUVANANTHAPURAM ON4~nI DECEMBER, 1998.

List of participants is enclosed atAnnex-1.

Chief Engineer (SP&A) welcomed all the participants to the StandingCommittee meeting and stated that the, meeting was primarily called to discussand finalise the transmission system associated with 7 ti

' unit (500 MW atRamagundam STPS) and also the transmission systcm rcquired ('or slrell!'thcllillgoCthe Southern Regional grid to enilble the constituents to absorb the poweravailable from the Eastern and Western Regions. The agenda was thereaftertaken up for discussion.

I. Transmission system associated with Ramagundam 7°' Unit (500 MW) :

Chief Engineer (SP&A) stated that Central Electricity Authority hadalready accorded techno-economic clearance for installation of iJdditional 500Wcap?city at Ramagundam STPS of NTPC. To enable POWERGRJD tocommissIon, the assoc.iated tnmsrnission systen1 to n1atc.h \\lith the. CO!~:::1issionjngof generation, it was necessary that the system component be also iin21ised andgot· approved by POWERGRlD. For identifying the transmission systemassociated witI-? this additional capacity, Central Electricity Authority had alre3dycarried out transmission system planning studies. Considering tlmt the import ofpower from the Western Region over the ChandrilPur-RamagundiJlll lill~ whichwas also 10 be translnitled over the transmission syslem ('rom Rall,agullcblll, thestudies had considered the import of power alongwitll full generation ,capacity atRamagundam STPS so· that the transmission system so planned is capable ofutilising the Cull quantum of power at Ramagundam alongwith import i"om theWestern Region. Further, another project near Ramagundam to, be im!)iementedby M/s.BPL with a capacity of' 520 1vIW had also been accorded teclll;o-economicclearance of Central Electricity Authority. For evacuation of power fi·ol11 thisproject, APSEB was separately implementing associated transmission system

. which inter alia covers the following transmission facilities:

i)ii)iii)

BPL - DiehpallyBPL - Gaijwet-Hyderabacl.B~L-· Ramagundam

400 kV SiC400 ~V SIC220 kV ole

He added that the results of the studies carried out by Central ElectricityAuthority had already been brought out in the agenda paper and the same had.been circulated to all thc constitucnts.

Annexure IV - Page 1 of 3Annexure CS.1 (Page 114 of 144)

Discussing the r~sults'of studies carried out, .it. was pointed out by CE(SP&A) that an additional SIC Iin~ from Ramagundam to Hyderabad and onwardsto Gooty was considered and it was found that with this line and considering fullgenerl!tion in the northern part of the Southern Regional grid .(including full

. generation at Ramagundam, import from Western Region, full generation atSimliadri a'nd Vizag complex including import from EasternRegion) the loadingon the Ramagundam-Gooty corridor was satisfactory. However, the 400 kVRamagundam-Kharnmam line was not evacuating any power from Ramagundamand on the contraly illjecting the power from Simhadri"Vizag complex towardsRamagundam and the Gooty-Bangalore line was also getting overloadcd.Accordingly, it was felt that in addition to the line from. Ral1lagtindam-Gooty viaHyderabad ,the follQwing additional cjrcuits would also be required for reliableevacuation of power from Ramagundam:

i)ii)

Khammam-Nagarjun,\sagarGooty-Bangalore

400 kV SIC400 kV SIC

Chief Engineer (SP&A) further stated that in' addition to the abovetransmission facilities, the LILOof 400 kV Vijayawada-Srisailam D/C line, beingconstructed by APSES, at Nagarjunasagar, and creation of 400 kV Substation atKalwakurthy by LILO of the Hyderabad-Srisailam 400 kV SIC line andNagarjunasagar-Gooty 400 kV SIC line as weI) as the LILO ofNaga~iunasagar

Gooty 400 kV SIC line at Karnool and the Hyderabad-Gooty (proposed above)line at Karnool would be required. It w'!s observed that the !lbove arrangementsresulted in reduction of about 170 MW in the lotal system losses. He requestedthe constituents to give their comments.

,-'

Executive Director( Engg.), POWERGRlD stated that it was necessary toutilise the transmission. con'idors optinlally and hc , therefore. suggested lhatinstead of the 400 kV SIC line lI'om Raillagundam toHyderabad, a DIe: line shouldbe constructed. .

Chief Engincer , APSEB slaled that the LlLO of Vijayawada-Srisailalll al

~'\ Nagarjunasagar would need to be examined keeping in view the requirements of

pumping power at Srisailam during the oft:peak conditions. "He, thercCorc,suggcsted carrying out of load flow studies corresponding to pumping modc oCthe SrisaiJam station beforc a decision was taken on thc LlLO of VijayawaclaSrisailam at Nagarjunasagar.

Chief Engineer,KES-suggested that the loads around Chintamani , north

I'·t of Kolar wcre'de\leloping very fast and the second 400 kV line bctwcen Gooty

and Bangalore sliould be routed via Chintamani.

Chief Engineer, TNEB stated that thcre wos a nccd for strcngthening theline bctween Cuddapah and North Madras by constnJcting an additional 400 kVline in the corri,for.

"0:,;.-


;

iIi

i.

\'

;.'.,

>"{<"f~ik~l'i,'.",," '.... , ,,~.,',.,'. .." ; ,':,))" .:, }!L',';"::;,ii.'!'{?;,'8+0X'!'esfe'h Enginee;;:(SP&A)reSpondi~~·.,~;,::ilf(6d~~i~i~Of. ,.the·· .m~mb~rs

~!: ,. ,,' 'J stat~d,:ib'a:t':fdfevacuation;6fpowerfromRamagU'll,aJiii:~r.;a&dit10naI SIC line' was·.. ·t:ad~quate',;·consideririg>that.·; 'with <the , aclditionof .400.,kVKhammam -":Nag~iJi,ina~agar 'line the Ramagundam-Khammanl. se<;ti'9rl.was carryirigrnore than

20QMW'imd' therefore;' the proposed' D/Clineby;PQWERGR1Dcould .be.·.c()nsid~fedas a composite transmission system beingplanmid by APSEB asa part. ofI3Pl.;TPSand thesharinii:&thecostofthis D/Cjine c()uld be mutually settled

between !'OWERGRlD and'APSEB 50 that the objective ofoptiillising the right-6f-wiiY was also achieved." .

"Keg'arding the establishment of a new substation atChintamani, he stated. that.,alieadya400'kV SUbstation;at Kolar was being established as pali of. Talcher-II project and the ,new subs.tation could be implemented by KEB by LILO'. of4'OQ kV line ofPOWERGRID passing near the substation location, Regarding,the'LILOofVijayawada-Srl'sailam atNagarjunasagar,Chief Engineer (SP&A),Central Electricity Aiitlionty' stated that Srisailam WaSCOIJIJected to Ramagundamvia'HyClerabad as wel1?asNag~ju'nasagarwhicli;wouldprovide the requiredpumping power, in additiorilothepower from theSimhadri and Vizag complex,As such the apprehensions about not meeting the pumping requirements ofSrisailam project did not hold good. However; he agreed to carry out theaClditional studies for .•. off_peak load conditions to confirm the adequacy oftransmission for pumping mode at Srisailam project.

Regarding the proposalofTNEB for strengthening of the Cuddapah-NorthMadras -1ine he stated that the proposal was being discussed in the next point ofthe agenda,

After further discussions the following transmission system'was finalise"for evacuation or"power from the 7th unit at Ramagundam STPS: \b'

';

i)ii)iii)iv)

Ramagundam-HyderabadHyderabad-Karnool-GootyGooty-Bangalore(Nelamangala) .Khammam-Nagarjunasagar

400 kV DIC line;,400 kVS/C 1/400 kV SIC I400 kVS/C!

It was also agreed that jf required one circuit of the Ramagunc!amHyc!craffiHI-400 kV Die title cnrl,be:ULtJc"tl At(jPL by :\I'Sr:ll "t their eOSf as this

"~ 'would provide reliabllily dhvtiblUlHbli o!'ptwM £ttl,,; the project.


Anil-CTU

Rectangle


System Planning & Project Appraisal Division

Sewa Bhawan, R.K. Puram, New Delhi – 100 66.

No. 51/4/SP&PA-2001/ Date : 30th January, 2003.

To

1.The Member Secretary,

Southern Regional Electricity Board,

29, Race Course Cross Road,

Bangalore 560 009.

FAX : 080-2259343

2.The Executive Director (Engineering),

Power Grid Corp. of India Ltd.

B-9, Institutional Area, Katwaria Sarai,

New Delhi 110 016.

FAX : 011-6466823, 6564751

3.The Director (Transmission),

Transmission Corp. of Andhra Pradesh Ltd.,

Vidyut Soudha,

Hyderabad – 500 082.

FAX : 040-3317652, 3320565


Karnataka State Power Transmission Corp. Ltd.,

Cauvery Bhawan,

Bangalore 560 009.

FAX : 080 -2228367, 221352

5.The Member (Transmission),

Kerala State Electricity Board,

Vidyuthi Bhawanam, Pattom, P.B. No. 1028,

Thiruvananthapuram - 695 004.

FAX : 0471-446774

6.The Executive Director/ Planning,

Tamil Nadu Electricity Board,

6th

Floor, Eastern Wing, 800 Anna Salai,

Chennai – 600 002.

FAX : 044-8521210, 8544528

7.The Director (Power),

Corporate Office, Block – I,

Neyveli Lignite Corp. Ltd., Neyveli,

Tamil Nadu – 607 801. FAX : 04142-52646

8.The Superintending Engineer –I,

First Floor, Electricity Department,

Gingy Salai,

Pondicherry – 605 001. FAX : 0413-334277

9.The Executive Director (Engineering),

NTPC Ltd., Engg. Office Complex,

A-8, Sector 24,

Noida – 201 301.

FAX : 91-539462, 91-4410136, 91-4410137


Nuclear Power Corp. of India Ltd.,

12th

Floor,North Wing,Vikram Sarabhai Bhawan,

Anushakti Nagar,

Mumbai – 400 085. FAX : 022- 5556513

11. The Director (Tech),

Power Trading Corpn. of India Limited,

2nd

Floor, NBCC Tower,

15 Bhikaji Cama Place, NewDelhi 110066. FAX-011-51659504

Sub: Sixteenth meeting of the Standing Committee on Power System Planning in Southern

Region.

Sir,

Enclosed please find summary record of discussions in the 16th meeting of the Standing Committee on

Power System Planning in Southern Region held at Kaiga on 20th January 2003.

Kindly acknowledge the receipt.

Yours faithfully,

Encl: As above.

(A.K. Asthana)

Director (SP & PA)

Annexure V - Page 1 of 13Annexure CS.1 (Page 117 of 144)

Summary record of discussions in the 16th

meeting of the Standing

Committee on Power System Planning in Southern Region,held at Kaiga on

20th

January 2003.

List of participants is enclosed at Annex-I.

Station Director, Kaiga APP Generation Station, NPCIL welcomed the participants and

gave a presentation on the achievements and future programme of nuclear generation capacity

addition by NPCIL. He also mentioned the difficulties that were being faced by the Kaiga APP

on account of grid operational problems and the need of improving the maintenance of

protection system at Hubli substation of KPTCL.

Chief Engineer (SP&PA), CEA welcomed all the participants to the 16th

standing

committee and thanked NPCIL for arranging the meeting at Kaiga APP and for making

excellent arrangements. He requested Director(Transmission), KPTCL to look into the

problems of operational coordination between Kaiga APP and KPTCL substations and

protection system at Hubli. Director(Transmission), KPTCL agreed to look into the matter and

assured that whatever was necessary, would be done.

The agenda items were thereafter taken up for discussion.

1. Confirmation of Summary record of discussions of the 15th

Standing Committee

Meeting.

Chief Engineer (SP&PA), CEA stated that the summary record of the 15th

meeting held

on 18-4-02 at Bangalore were circulated vide No.51/4/SP&PA –2002/184-97 dt. 24-4-

2002 and no observations or objections have been received from any participant.

Thereafter, the summary record was taken as confirmed.

2. Review of progress on the decisions taken in the 15th

meeting.

2.1 Provision of new 400kV sub-stations and additional transformers at existing s/stn.

Chief Engineer (SP&PA), CEA stated that based on discussion in the last meeting,

proposal for new 400kV substations and additional transformers at existing substations

under regional scheme, had been considered and it was proposed to include the

necessary provisions under the Regional Transmission System for Kaiga Extension

(Unit-3 & Unit-4, 2 x 235 MW) and Neyveli TS-II Expansion (2 x 250 MW) Projects,

covered under agenda item-5.

2.2 Kaiga Stage-I Transmission System – Upgrading Kaiga-Sirsi-Davanagere line for

400kV operation

The progress of works for upgraded operation of Kaiga-Davanagere line to 400kV was

reviewed. NPCIL intimated that the work at Kaiga end would be ready by December

2003.

In regard to works at Davanagere end, Director (Transmission), KPTCL informed that

tenders had was already been invited. The technical bids had been opened and the cost


bids were to be opened shortly. However, before KPTCL proceeded further, decision

on the cost sharing of the Sirsi-Davanagere section of the line was required.

The issue was discussed and it was noted that the Sirsi-Davanagere section of line of

KPTCL would become an integral part of Kaiga-Davanagere 400kV D/C line. Also,

there would not be any 400kV switching station at Sirsi. As such, the Sirsi-Davanagere

section of 400kV Kaiga-Davanagere D/C line as well as the two 400kV line bays that

were required to be provided by KPTCL would qualify to be a part of regional system

in all respect.

In view of this, it was agreed to include the Sirsi-Davanagere line section and the two

400kV bays at Davanagere under the regional scheme and it was decided that MS,

SREB would take-up this issue for getting this endorsed in the SREB forum. However,

this would be treated as a specific case and not linked the proposal for transfer of other

transmission system of State utilities under the Regional category that was being

discussed separately in the SREB.

It was also decided that KPTCL would go ahead with the works for provision of bays at

Davanagere end and not wait for the SREB process.

2.3 LILO of second circuit between Kadra and Kodasalli at Kaiga.

CE (SP&PA), CEA stated that the views of NPCIL and KPTCL forwarded to CEA on

the LILO proposal were examined and as this was more of an operational issue, the

matter should be shorted out by KPTCL and NPCIL between them or in the Operating

Committee of SREB.

2.4 Kaiga-Narendra 400kV D/C Line and Narendra 400kV Substation

POWERGRID representative intimated that the forest clearance for construction of

Kaiga-Narendra 400kV line had finally been obtained in November 2002. For

establishment of Narendra 400kV S/S they were in process of preparing FR for

obtaining approval of their Board. The construction schedule of 400kV Kaiga-Narendra

line along with Narendra 400kV S/S was being programmed for completion and

commissioning by March 2005.

In regard to commissioning of Kaiga Stg-II, NPCIL informed that civil construction

works for Kaiga Stg-II project was going on at rapids pace and the project was

presently scheduled for commissioning by December 2006.

3. Co-opt of PTC as a member of standing Committee.

CE(SP&PA) stated that the PTC was a facilitator for trading of power to beneficiary

states of different regions .The role of PTC was significant considering the power

deficit in Southern Region and possibilities of meeting the gap through supply of power

from other regions especially from the surplus available in Eastern Region. PTC was in

a better position to provide information regarding emerging power exchange modalities

and availability of power from future generating stations enabling decision for purchase

of power judiciously. He requested the members to give their views on the proposal.


Director, PTC, an special invitee to the meeting, elaborated upon the role being played

by PTC in the power trading.

Director (Trans), APTRANSCO and Director (Trans), KPTCL wanted to know whether

PTC would be invited as special invitee or as a member of the committee and what

would be its role in the process of agreement or decision on the issues.

CE(SP&PA), CEA stated that it was proposed to co-opt PTC as a member of the

committee. He further explained that the decisions in the Standing Committee were

arrived on the basis on consensus among those members of the Standing Committee

who were the affected parties for the particular issue. As such, the role of PTC would

be more towards providing information and in participative discussions on issues, and

not in decisions relating to regional transmission where they had no stake.

After discussions all the other members of the Committee unanimously agreed for

induction of PTC as a member of the Standing Committee of the Southern Region.

4. National Grid for Southern Region:

Inter-regional transmission system for import of additional power by the Southern

Region from operational surpluses in Eastern and other regions and providing all

India connectivity:

Chief Engineer (SP&PA), CEA stated that many thermal power projects in Eastern

Region like Kahalgaon Extension, Barh, Maithon RBC, North Karanpura, etc were being

envisaged to come up during the 10th

and 11th

Plan periods and generation from these

plants would be transported to neighboring deficit regions. Formation of National Grid

connecting Eastern Region with the Northern Region and Western Region was being

envisaged in this context. With Rourkela-Raipur inter-connection, the Western Region and

by year 2005 the Eastern Region would start operating in synchronous mode very shortly.

Subsequently, with Tala transmission system, the Northern Region and Eastern Region

would also get inter-connected synchronously. North Eastern Region was already

operating with synchronous AC inter-connection with Eastern Region. With this, all

regions except the Southern Region would be in synchronous operation. With

strengthening of National Grid network associated with Barh and Kahalgaon etc., the total

network of ER, NER, WR and NR would operated as an integrated system. It was

proposed to extend the National Grid to the Southern region also so that an all India

integrated grid could be realized.

Director (SP&PA), CEA gave a presentation on the proposal of extension of the National

Grid for Southern Region (enclosed at Appendx-1). The presentation highlighted that with

the demand projection as per 16th

EPS and generation programme that was being

envisaged, the Southern Region would need an additional tie-up for 2000 to3000 MW for

meeting the full supply requirements by 2008-09. This would be in addition to supply

from Talcher-II, 2000 MW and imports of about 1000 MW via Gazuwaka HVDC back-to-

back link. Further, as the current trends of demand growth incase of the Southern region

were higher than the 16 EPS projections, the requirement of additional tie-up could be still

higher if the demand growth in Southern region continued as per the current trend. A cost

effective possibility for meeting this demand would be through import from Eastern

Region. For enabling this import and providing all India inter-connectivity, it was

proposed to include the Southern region also under the ambit of National Grid by


extending the 765kV network up to Raichur. Studies to evolve the required system had

been carried out in CEA and circulated along with the agenda. A review of the options

considered, results of the studies and an indicative cost comparison of the alternatives

were also presented (please refer to Appendix-I for details).Indicative cost for option-I,AC

Alternative was Rs.3200 crores, for option-2,Hybrid Alternative was Rs.5000 crores and

for option-3, HVDC Alternative was Rs.5800 crores.

The members generally agreed to the need of National Grid connectivity for the Southern

Region.Of the 3 alternatives, the choice was generally between Alt-I and Alt-II.

Director (Transmission), KPTCL asked regarding adoptability of 765 kV transmission

system and the cost difference between 400kV Quad conductor lines and 765kV lines.

Chief Engineer (SP&PA), CEA clarified that 765kV voltage level has been well accepted

level as next higher transmission voltage. As compared to 400kV D/C Quad conductor

line, the cost of 765kV S/C line was less as it had only 12 conductors against 24 in case of

the former. However, in case of 765kV, the cost of substation equipments was higher. On

over all basis the two were more or less at the same level of cost. The two were also

comparable in respect of thermal limit of transmission capacity. However, the main

advantage of 765kV level was due to its high SIL, which enables 765kV system to provide

higher transmission capacity over longer distance with stability.

ED (Engg.), POWERGRID suggested that National Grid formation and integrated

operation of regions should be implemented in a phased manner. He further stated that

though AC option worked out to be economical it would be prudent to go for Hybrid

system for SR National Grid for operational considerations.

Director, APTRANSCO emphasized that priorities should be given to security and

reliability aspects towards formation of the SR National grid and stated that Hybrid

System, though it appears to be a little costlier, could be envisaged.

Member (Technical), KSEB stated that after Talcher-Kolar HVDC bi-pole link was fully

realized, it would be preferable to go for option-1 for formation of Southern National

Grid. He suggested that planning of Southern National Grid should be made in stages for

short and long term basis. CE, TNEB supported the views of KSEB.

CE (SP&PA), CEA suggested that all the constituents could again go through the studies

circulated along with agenda in light of the presentation and discussions during the

meeting and sent their suggestions to CEA by the end of February 2003. Based on the

inputs, CEA would carry out further studies to firm up the proposal and the same could be

discussed and finalized in the next meeting.

5. Review of the proposal for LILO of 400kV Gazuwaka-Vijaywada D/C line at

Vemagiri and Signing BPTA for implementation of 400kV Rourkela-Riapur-

Chandrapur scheme

Chief Engineer(SP&PA) stated that the LILO of Gazuwaka-Vijaywada 400kV D/C line

at Vijaywada was agreed to in the 15th

meeting of the standing committee meetings

subject to completion of Vemagiri-Tadikonda 400 kV D/C lines by APTRANSCO.

However, in view of APTRANSCO and TNEB not agreeing for sharing of the

Rourkela-Riapur-Chandrapur 400kV system evolved as a fall-back transmission system

for Talcher-II and agreed in the 12th

meeting of the standing committee, the


implementation of fallback system for Talcher-II has been held up. The need for review

of Vemagiri LILO proposal had been felt in this context. In a meeting taken by

Chairman, CEA with the SR constituents on the issue of signing BPTA for

implementation of 400kV Rourkela-Riapur-Chandrapur scheme, APTRANSCO

representative had stated that instead of sharing transmission charges for the suggested

fall back system, they would prefer to carry out load shedding. With application of this

planning criteria/philosophy, the need for LILO of Gazuwaka-Vijaywada at Vemagiri,

which was also a fall back arrangement for meeting the contingency of outage of

Vemagiri-Tadikonda line, was also arguable.

The issue was discussed in detail. KPTCL informed that they have already conveyed

their agreement for the 400kV Rourkela-Raipur-Chandrapur D/C line. CE (SP&PA),

CEA emphasised the urgency of signing the BPTA for the Rourkela-Riapur-

Chandrapur scheme so that fall back system could be put in place. Director

(Transmission), APTRANSCO requested CEA to forward a consolidated note on the

issue so that the matter could be taken up for a review in his organization. CE

(SP&PA), CEA stated that all the necessary information was already available with

APTRANSCO in their record. However, he agreed to send a note covering background

on the issue and justification details for taking up the scheme so as to facilitate the

review process by APTRANSCO and TNEB (and also by KSEB, KPTCL and

Pondichery for expediting signing of BPTA).

6. Additional Transmission system for Kaiga APP Stage-II (3rd

and 4th

Units), and

Evacuation system for Neyveli TS.II Expansion Project (2x250 MW).

CE(SP&PA) stated that upgrading and operation of the existing Kaiga-Sirsi-

Davanagere D/C line at 400kV level and adding Kaiga-Narendra 400kV D/C line as

part of approved Kaiga evacuation system would not be sufficient to meet stringent

requirements for the Nuclear Stations. Also, with addition of 2x235 MW under Stage-II

of Kaiga, taking total capacity at Kaiga to 910 MW, additional transmission lines from

Narendra were needed for dispersal power towards Devanagere and from thereon to

load centers in South Karnataka and North Kerala. He further stated that Neyveli TS.II

Expansion Project (2x250MW) was also coming in the region in the same time frame

and transmission system the same had also to be evolved. Accordingly, CEA had

carried out studies for evolving the required transmission system. The result of the

studies and the proposal system had been circulated with the agenda. This was required

to be discussed to finalise the transmission system.

Thereafter, the proposal as contained in the agenda note was discussed in detail and

based on the technical need of system strengthening for evacuation and dispersal of

power from the extension projects and also for taking care of requirements arising out

of changes in flow pattern on account of growth in demand and redistribution of power

flows, the following decisions were taken:.

(a) It was agreed that in addition to new 400kV substations with 2x315MVA capacity

at Mysore (Karnataka), Kozhikode (Kerala), Pondichery and Pugalur (TN) and

second 315 MVA transformer at Vijaywada as proposed in the agenda, additional

400kV substations with 2x315MVA capacity at Warangal (A.P.) and Melakottaiyur

(TNEB) were also needed and it was decided to include these under the regional

scheme.


(b) The need for one additional 315 MVA 400/220 kV additional transformer each at

Davanagere substation of KPTCL (2nd

transformer) and Trissur substation of KSEB

(3rd

transformer) was also noted. However, as Davanagere and Trissur were already

existing substations of KPTCL and KSEB respectively, the additional transformers

would be provided by the respective utilities owing the substations at their own cost

and compensatory provision under the regional scheme would be covered in some

future scheme.

(c) KPTCL suggested that 400kV substations proposed at Haveri could be deleted and

instead, second 315 MVA transformers at Hiriyur could be provided. This was

agreed.

(d) In regard to the suitability of taking line to Mysore from Somanhalli via-a-vis from

Neelamangala 400kV S/Ss, KPTCL stated that Neelamangala would be better point

to take-off the line from system and ROW consideration. Accordingly, it was

decided to have the line from Neelamangala.

(e) Taking note of result of studies for evolving evacuation system for Kudankulam,

which were circulated as a supplementary agenda, it was decided that instead of

taking towards Trichy or Udumalpettai, the 400kV line from Neyveli to Pugalur

would be extended towards Mudrai.

(f) TNEB suggested that 400kV substation proposed at Villupuram could be deleted

and instead, 400kV substation at Arasur could be provided. This was agreed. It was

also decided that instead of LILO of Salem-Udumalpet as was proposed earlier by

TNEB, the interconnecting arrangement for Arasur substation would be 400kV

Udumalpet-Arasur D/C line, because this would fit better in the perspective

scenario.

(g) On suggestion of POWEGRID, KPTCL and TNEB, it was agreed that the 400kV

lines that were proposed to be S/C would be revised to D/C. Though this would

result in lower initial utilization, this decision was taken with a view to reduce

multiplicity of lines in long run and save ROW.

Accordingly, it was decided that the following works would be covered under the

regional transmission schemes for Kaiga-II and Neyveli-II Exp. systems:


(1) Narendra-Davanagere 400kV D/C

(2) Neelamangala-Mysore 400kV D/C

(3) Mysore-Kozhikode 400kV D/C

(4) LILO (1xD/C) of 400kV Kolar-S P Budur line at Melakottaiyur

(5) New 400/220kV,2x315MVA substations at Mysore, Kozhikode and

Melakottaiyur

(6) S/S extn for line bays at Narendra, Davanagere and Neelamangala

(7) Second 400/220kV,315MVA transformer at Vijayawada and Hiriyur

Neyveli TS-St.II Expansion Transmission system:

(1) Neyveli TS-II Expansion-Neyveli TS-II 400kV 2xS/C

(2) Neyveli TS-II Expn.-Pugalur 400kV D/C

(3) Pugalur—Madurai 400kV D/C

(4) Udumalpet-Arasur 400kV D/C

(5) LILO (1xD/C) of Neyveli-S.P.Budur 400kV S/C at Pondicherry

(6) LILO (1xD/C) of Ramagundam-Khammam 400kV S/C at Warangal

(7) New 400/220kV, 2x315MVA substations at Pugalur, Arasur, Pondicherry

and Warangal

(8) S/S Extn for line bays at Madurai and Udumalpet


Early scheduling of works;

Director (Transmission), KPTCL informed that KPTCL had desired to construct

Neelamangala-Mysore 400kV D/C line along with Mysore 400kV substation (part of

regional transmission works under Kaiga Stage-II) ahead of the commissioning of the

generation units so as to facilitate supply to Mysore area for which full transmission

charge was proposed to be borne by KPTCL till commissioning of the first generating

unit (U#3 or 4) at Kaiga APP. Member, KSEB and Chief Engineer, TNEB made

similar suggestions in respect of Kozhikode and Melakottaiyur substations. It was

agreed that the respective utilities might take up with POWERGRID for needful.

7. Construction of Raichur-Gooty 400kV D/C line instead of earlier agreed proposal

for LILO of Hyderabad- Kurnool 400kV S/C line (part of Ramagundam –III transmission system) at

Raichur.

CE (SP&PA) stated that based on route survey, POWERGRID had informed that LILO

of Hyderabad-Kurnool line at Raichur, which was decided in the 12th

meeting, would

involve construction of a 400kV D/C line of about 95 km length, which was quite long.

In view of this, there was a need to review the proposal and it was proposed that instead

of the LILO, a 400kV D/C line from Raichur to Gooty as was suggested by KPTCL

earlier, could be considered. The Raichur-Gooty line was also found to fit well into the

plan of National Grid for Southern Region, presentation on which was made during the

meeting. Director (SP&PA), CEA stated that as per the studies for National Grid for

Southern region, the requirement of 400kV Raichur-Gooty D/C line with QUAD

conductor was found under the AC and Hybrid alternatives. The proposal was then

discussed in light of presentation on National Grid for Southern region and it was

agreed to include the construction of the line under the regional strengthening scheme.

8. LILO of Nellore-Sriperumbudur line at Alamathi S/S of TNEB.

CE (SP&PA) stated that based on route survey, POWERGRID had informed that the

route length for LILO of Nellore-S.P.Budur line at Alamathi was coming out to be

about 85-90 km and therefore, they had proposed that instead of LILO of both circuits,

as was agreed earlier in the 12th

meeting, which would require 2xD/C lines, only one

circuit could be LILOed.

ED, POWERGRID stated that as per the studies carried out by them, LILO of only one

circuits was also found to suffice the purpose of providing the required connectivity for

Alamathi.

CE,TNEB stated that the route length for the LILO would only be of the order of 55 km

and as such LILO of both circuits as already agreed should be retained.

CE (SP&PA), CEA stated that if the load requirements could be satisfactorily met with

LILO of only one circuit, one circuit LILO may be taken up in first phase and if need

be, the second circuit could be LILOed at a later date.


9. Execution of LILO/bay extension works at Mehboobnagar S/S of APTRANSCO

for LILO of Nagarjunasagar-Raichur 400kV S/C line and LILO/bay extension

works at Alamathi S/S of TNEB for LILO of Nellore-Sriperumbudur 400kV line.

CE (SP&PA) stated that confirmation was required from APTRANSCO and TNEB

about their position with respect to the execution arrangement for the bay extension

works at Mehboobnagar S/S and Alamathi S/S, LILOes which were decided in the 12th

meeting. The bays at their respective substations were required to be executed by them

as part of regional scheme at the cost of POWERGRID. Director (Transmission),

APTRANSCO and Chief Engineer, TNEB confirmed their agreement to the proposed

arrangement. It was clarified that POWERGRID would pay the respective cost and

recover transmission charges as part of regional transmission system. All the members

took note of this.

10. Evacuation arrangement for Kudankulam APP Stage-I (2x1000MW)

Director (SP&PA), CEA stated that Kudankulam APP Stage-I (2x1000MW) was planned

for commissioning at the start of 11th

Plan, that is first unit in 2007-08 and the second unit

in 2008-09. The transmission system for evacuations of power from Kudankulam was

required to be evolved and finalized so that it could be programmed for commissioning

matching with generation programme. Though the shares of the beneficiaries of

Kudankulam were yet to be finalized, transmission requirements for evacuation of power

from the project could be evolved as actual delivery of power would be through

displacement, and Kudankulam being located at an extreme end, the transmission system

would be practically independent of share allocation from generation. In this context, CEA

had carried out studies and the results of the studies along with proposed evacuation

network was circulated as a supplementary agenda. The following system was proposed:

FOR EVACUATION

• LILO (2xD/C) of both circuits of Madurai-Thiruvananthapuram 400 kV D/C line

at Kudankulam.

• Kudankulam-Thiruvananthapuram-Pallom-Trissur 400 kV D/C Quad line

• New 2x315 MVA 400kV substation at Pallom

• Third 315 MVA transformer at Thiruvananthapuram

FOR START-UP POWER

• Tuticorin-Kudankulam.220kV S/C Zebra conductor

• Thiruvananthapuram-Kudankulam 220 kV S/C Zebra conductor, if ROW permits

else, Kayathar-Kudankulam 220kV S/C Zebra conductor

ED (Engg.), POWERGRID stated that getting ROW in Kerala was very difficult and

suggested that Kayathar substation in Tamil Nadu which was en-route to Madurai-

Thiruvananthapuram line could be a better point for KAPP evacuation . POWERGRID

also circulated a new proposal during the meeting.


Member, KSEB stated that they could provide ROW for establishment of 400 kV lines

under Central Sector by dismantling of unloaded 220 kV and downward transmission lines

in their system.

ED (Engg.), POWERGRID suggested that a joint survey by CEA, POWERGRID and

KSEB would require to be carried out to find the availability of ROW/Corridors in Kerala

before firming of transmission system for KAPP projects. The same was agreed and it was

decided that the programme of joint survey would be finalized separately.

GM,NTPC stated that NTPC was proposing extension project at Kayamkulam and it

would be desirable that the evacuation from this project may be examined along with

Kudankulam project.

Based on the above discussions, it was decided that evacuation and start-up power system

for KAPP would be reviewed based on outcome of joint route survey and further review

studies to be carried out considering Kayamkulam Extn. Project.

11. Summary of decisions:

• KPTCL to look into the problems of operational coordination between Kaiga

APP and KPTCL substations and protection system at Hubli.

• Summary record of discussions of the 15th

Standing Committee Meeting as

circulated vide No.51/4/SP&PA –2002/184-97 dt. 24-4-2002 were confirmed.

• The Sirsi-Davanagere section of 400kV Kaiga-Davanagere D/C line as well as

the two 400kV line bays that were required to be provided by KPTCL at their

Davanagere substation would qualify to be a part of regional system in all

respect.

• MS, SREB would take-up for getting this endorsed in the SREB forum.

However, this would be treated as a specific case and not linked the proposal for

transfer of other transmission system of State utilities under the Regional

category that was being discussed separately in the SREB.

• KPTCL would go ahead with the works for provision of bays at Davanagere

end and not wait for the SREB process and schedule commissioning to match

with commissioning 400kV S/S at Kaiga targeted presently for Dec, 2003.

• PTC was co-opted as a member of Standing Committee.

• All the constituents would again go through the proposal for National Grid for

Southern Region and the studies circulated along with agenda in light of the

presentation and discussions during the meeting and sent their suggestions to

CEA by the end of February 2003. Based on the inputs, CEA would carry out

further studies to firm up the proposal and the same could be discussed and

finalized in the next meeting.

• CEA would circulate a note covering background on the issue and justification

details for taking up the scheme so as to facilitate the review process by


APTRANSCO and TNEB (and also by KSEB, KPTCL and Pondichery for

expediting signing of BPTA).

• The following works would be covered under the regional transmission schemes

for Kaiga-II and Neyveli-II Exp. systems:


1. Narendra-Davanagere 400kV D/C

2. Neelamangala-Mysore 400kV D/C

3. Mysore-Kozhikode 400kV D/C

4. LILO (1xD/C) of 400kV Kolar-S P Budur line at Melakottaiyur

5. New 400/220kV,2x315MVA substations at Mysore, Kozhikode and

Melakottaiyur

6. S/S extn for line bays at Narendra, Davanagere and Neelamangala

7. Second 400/220kV,315MVA transformer at Vijayawada and Hiriyur

Neyveli TS-St.II Expansion Transmission system:

1. Neyveli TS-II Expansion-Neyveli TS-II 400kV 2xS/C

2. Neyveli TS-II Expn.-Pugalur 400kV D/C (it is TS II exist.-Pugalur)

3. Pugalur—Madurai 400kV D/C

4. Udumalpet-Arasur 400kV D/C

5. LILO (1xD/C) of Neyveli-S.P.Budur 400kV S/C at Pondicherry

6. LILO (1xD/C) of Ramagundam-Khammam 400kV S/C at Warangal

7. New 400/220kV, 2x315MVA substations at Pugalur, Arasur,

Pondicherry and Warangal

8. S/S Extn for line bays at Madurai and Udumalpet

• For early scheduling of works, with the arrangement that requesting state utility

would be bearing full transmission charges till transfer of assets under regional

works, the respective utilities might take up with POWERGRID for needful.

• Instead of LILO of Hyderabad-Kurnool line at Raichur, (which was decided in

the 12th

meeting), Raichur-Gooty 400kV D/C line with QUAD conductor would

be taken up for construction under the regional strengthening scheme.

• In view of longer route length, instead of LILO of both circuits of Nellore-

S.P.Budur line at Alamathi as agreed earlier, LILO of only one circuits would

suffice the purpose of providing the required connectivity for taking up in first

phase and, if need be, the second circuit could be LILOed at a later date.

• A joint survey by CEA, POWERGRID and KSEB would be carried out to find

the availability of ROW/Corridors in Kerala and the proposal for evacuation

and start-up power system for Kudankulam APP would be reviewed based

on outcome of joint route survey and further studies considering Extn. Project at

Kayamkulam.


List of Participants

The following Officers participated in the 16th

Standing Committee Meeting on Power System

Planning in Southern Region held on 20th

January,2003 at Kaiga NPCIL.

Name Designation


1. ShriV.Ramakrishna Chief Engineer (SP&PA)

2. Shri A.K.Asthana Director

3. Shri R.Saha Dy. Director

S.R.E.B.

1. Shri S.Sivan Member Secretary

2. Shri A.K.Yadav A.E.E.

POWERGRID

1. Shri R.N. Nyak Executive Director(Engg.)

2. Shri V.Lakshmpathi Add,l. Gen. Manager

3. Shri Y.K.Sehgal D.G.M.

4. Shri Pankaj Kumar D.G.M.

5. Shri Babu Varghese D.G.M.

6. Shri A.Chocualingam Chief Manager

7. Shri C.N.Suresh Babu Chief Manager

N.T.P.C

1. Shri N.N.Misra G.M.(Elect.)

N.P.C.I.L.

1. Shri K.J..Sebastian Director(Trans)

2. G. Nageswararao,Station Director(KGS)

3. V.Kausumu Director(E&P.)

4. Shri K.Ramamurthy CE(KGS 1&2)

5. Shri C.S.Malpatil C.E.(E&P)

6. Shri Rajesh Laad DGM(Trans)

7. R.C.Sinha P.D.

8. Shri R.V.Manohar SO1(TV)

P.T.C

1. Shri S.K.Dube Director

APTRANSCO

1. Shri G. Kesav Rao Director(Trans. & GO)


2. Shri M.Sitarama Sarma SE(Tech. & SS)

K.P.T.C.L.

1. Shri S.Shivamallu Director(Trans)

2. Shri S.K.Sridhara EE(Planning)

3. Shri S.Ramesh E.E.(Corp. off)

4. Shri Syed Zubair Ahamed Asstt.Ex.Engr. (Corp. off.)

5. Shri P.L.Manjunath Asstt.Ex.Engineer (Planning)

6. Shri K.Balaraman AE(Elect)

7. Shri S.M.Mudeshwar Section Officer(Kadra)

T.N.E.B.

1. Shri M.Duraira Chief Engineer(Plg.)

Neyveli Lignite Corpn.

1. Shri S.Rajaram Addl.Chief Engineer

K.S.E.B.

1. Shri C.Abdulla Member(Trans.)


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Annexure VII - Page 1 of 2Annexure CS.1 (Page 138 of 144)

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Annexure VIII - Page 1 of 5Annexure CS.1 (Page 140 of 144)





A. SRPC Members - Southern Regional Power Committee

Documents