भारत सरकार Government of India विद् युत मंत्रालय Ministry of Power उत्तर क्षेत्रीय विद् युत सवमवत Northern Regional Power Committee
क: 13.08.2021ﴂउ.क्षे.सव. ./प्रचालन/106/01/2021/ सदना :ﴂ
विषय: प्रचालन समन्वय उप-सवमवत की186िीं बैठक की काययसूचीI Subject: Agenda of 186th OCC meeting.
े 셍 के माध्यमﴂ प्रचालन मन्वय उप- समसत की 186िीं बैठक का आयोजन वीसियो कॉन्फ़्रᴂस क 18.08.2021 को 11:00 बजे े सकया जाये셍ा I उक्त बैठक की कायग ूची उत्ति क्षेत्रीय सवद्युत्ﴂसदना समसत की वेब ाइट http://164.100.60.165/ पि उपलब्ध हैI को ई-मेल द्वािा प्रदान सकया ﴂक व पा विग भी दोﴂबैठक मᴂ म्मिसलत होने के सलए सल जाए셍ा। कृपया बैठक मᴂ उपम्मथितहोने की ुसवधा प्रदान किᴂ।
186th meeting of the Operation Co-ordination sub-committee will be conducted through Video Conferencing on 18.08.2021 from 11:00 Hrs. The agenda of this meeting has been uploaded on the NRPC web-site http://164.100.60.165/.
The link and password for joining the meeting will be e-mailed to respective e- mail IDs in due course.
Kindly make it convenient to attend the meeting.
( ौसमत्र मजूमदाि) (ता (प्रचालनﴂअधीक्षण असभय
सेिामᴂ : प्रचालन समन्वय उप सवमवत के सभी सदस्य। To : All Members of OCC
ह मा셍ग, कटवारिया िाय, नई सदल्ली- 110016 फोन:011-26513265 ई-मेल: [email protected] वेब ाईट: www.nrpc.gov.inﴂ 18-ए, शहीद जीत स 18-A, Shaheed Jeet Singh Marg, Katwaria Sarai, New Delhi-110016 Phone: 011-26513265 e- mail: [email protected] Website: www.nrpc.gov.in खण्ड-क: उ.क्षे.वि.स. Part-A: NRPC
1. Confirmation of Minutes The minutes of the 185th OCC meeting which was held on 20.07.2021 through video conferencing were issued vide letter of even number dated 06.08.2021. Sub-committee may deliberate and kindly confirm the Minutes. 2. Review of Grid operations of July 2021 2.1 Power Supply Position (Provisional) for July 2021 Anticipated Power Supply Position v/s Actual Power Supply Position (Provisional) of Northern Region during the month of July-2021 is as under:
Energy (MU) Peak (MW) Req. State / UT % % / Avl. Anticipated Actual Anticipated Actual variation variation (Avl) 200 201 0.7% 360 426 18.3% CHANDIGARH (Req) 210 201 -4.1% 450 426 -5.3% (Avl) 5282 3720 -29.6% 7950 7323 -7.9% DELHI (Req) 4000 3721 -7.0% 7950 7323 -7.9% (Avl) 6400 6494 1.5% 11850 12120 2.3% HARYANA (Req) 5760 6496 12.8% 11700 12120 3.6% (Avl) HIMACHAL 884 1050 18.9% 1465 1598 9.1% PRADESH (Req) 862 1051 21.9% 1450 1598 10.2% (Avl) J&K and 2170 1445 -33.4% 3440 2462 -28.4% LADAKH (Req) 1440 1552 7.8% 2420 2712 12.1% (Avl) 7603 8184 7.6% 13600 13431 -1.2% PUNJAB (Req) 7543 8304 10.1% 13550 13431 -0.9% (Avl) 8740 8149 -6.8% 18120 13974 -22.9% RAJASTHAN (Req) 7900 8156 3.2% 13500 13974 3.5% (Avl) UTTAR 13330 13927 4.5% 23800 24795 4.2% PRADESH (Req) 13082 14063 7.5% 23800 24965 4.9% (Avl) 1401 1349 -3.7% 2080 2269 9.1% UTTARAKHAND (Req) 1442 1362 -5.5% 2100 2269 8.0% (Avl) NORTHERN 46010 44519 -3.2% 74900 72900 -2.7% REGION (Req) 42238 44906 6.3% 72900 73300 0.5%
As per above, negative / significant variation (≥5%) in Actual Power Supply Position (Provisional) vis-à-vis Anticipated figures is observed for the month of July-2021 in terms of Energy Requirement for Chandigarh, Delhi, Haryana, HP, UTs of J&K and Ladakh, Punjab, UP, and Uttarakhand and in terms of Peak Demand similar variation is noted for Chandigarh, Delhi, HP, UTs of J&K and Ladakh, Punjab, and Uttarakhand. These states/UTs are requested to submit reason for such variations so that the same can be deliberated in the meeting.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 2 of 38 All SLDCs are requested to furnish provisional and revised power supply position in prescribed formats on NRPC website portal by 2nd and 15th day of the month respectively for the compliance of Central Electricity Authority (Furnishing of Statistics, Returns and Information) Regulations, 2007.
2.2 Power Supply Position of NCR NCR Planning Board (NCRPB) is closely monitoring the power supply position of National Capital Region. Monthly power supply position for NCR till the month of July- 2021 is placed on NRPC website (http://nrpc.gov.in/operationcategory/power-supply- position). Power supply position during the current financial year is shown as under:
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 3 of 38
3. Maintenance Programme of Generating Units and Transmission Lines 3.1. Maintenance Programme for Generating Units a. The meeting on proposed maintenance programme for Generating Units for the month of September-2021 is scheduled on 17-August-2021 via Video Conferencing. 3.2. Outage Programme for Transmission Elements The meeting on proposed outage programme of Transmission elements for the month of September-2021 is scheduled on 17-August-2021 via Video conferencing.
4. Planning of Grid Operation 4.1. Anticipated Power Supply Position in Northern Region for September 2021 The Anticipated Power Supply Position in Northern Region for September 2021 is as under:
Revised Revised Peak State / UT Availability / Requirement Energy (MU) (MW)
Availability 170.0 350 Requirement 150.0 390 CHANDIGARH Surplus / Shortfall 20.0 -40 % Surplus / Shortfall 13.3% -10.3% Availability 3420.0 6600 Requirement 3550.0 6800 DELHI Surplus / Shortfall -130.0 -200 % Surplus / Shortfall -3.7% -2.9% Availability 5960.0 11550 Requirement 6070.0 10500 HARYANA Surplus / Shortfall -110.0 1050 % Surplus / Shortfall -1.8% 10.0% Availability 1620.0 3080
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 4 of 38 Revised Revised Peak State / UT Availability / Requirement Energy (MU) (MW)
Requirement 960.0 1570 HIMACHAL Surplus / Shortfall 660.0 1510 PRADESH % Surplus / Shortfall 68.8% 96.2% Availability 1940.0 3340.0 Requirement 1480.0 2620.0 J&K and LADAKH Surplus / Shortfall 460.0 720 % Surplus / Shortfall 31.1% 27.5% Availability 6550.0 10530 Requirement 7620.0 13080 PUNJAB Surplus / Shortfall -1070.0 -2550 % Surplus / Shortfall -14.0% -19.5% Availability 8490.0 18300 Requirement 7450.0 13410 RAJASTHAN Surplus / Shortfall 1040.0 4890 % Surplus / Shortfall 14.0% 36.5% Availability 13800 25000 UTTAR PRADESH Requirement 13500 25000 (Revised on Surplus / Shortfall 300 0 12.08.2021) % Surplus / Shortfall 2.2% 0.0% Availability 1390.0 2850 Requirement 1410.0 2150 UTTARAKHAND Surplus / Shortfall -20.0 700 % Surplus / Shortfall -1.4% 32.6%
Availability 43340 74900 NORTHERN Requirement 42190 69400 REGION Surplus / Shortfall 1150 5500 % Surplus / Shortfall 2.7% 7.9%
SLDCs are requested to update the anticipated power supply position of their respective state / UT for the month of September-2021 and submit the measures proposed to be taken to bridge the gap between demand & availability, as well to dispose of the surplus, if any, in the prescribed format.
5. Information about variable charges of all generating units in the Region The variable charges detail for different generating units are available on the MERIT Order Portal. All states/UTs are requested to submit daily data on MERIT Order Portal timely.
6. Submission of breakup of Energy Consumption by the states The updated status on the submission of energy consumption breakup is presented below:
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 5 of 38 State / UT From To DELHI Apr-2018 Jun-2021
HARYANA Apr-2018 May-2021
HIMACHAL PRADESH Apr-2018 Apr-2021
PUNJAB Apr-2018 Mar-2021
RAJASTHAN Apr-2018 Jun-2021
UTTAR PRADESH Apr-2018 Apr-2021
All the remaining states/UTs viz., Uttarakhand, UTs of J&K and Ladakh and Chandigarh are again requested to submit the requisite data w.e.f. April 2018 as per the billed data information in the format given as under:
Consumption Consumption Consumption Consumption Traction by by Miscellaneous Category→ by Domestic by Industrial supply Commercial Agricultural / Others Loads Loads load Loads Loads
7. System Study for Capacitor requirement in NR for the year 2019-20 7.1. In the 45th TCC/ 48th NRPC meeting, it was decided that the study report for 2019-20 along with the guidelines for finding the capacitor requirement at 11/33 kV level in NR would be submitted by CPRI. In the meeting, CPRI representative had stated that as there were diversified network configurations at the level of DISCOMs, the guidelines to be provided would be generalized and may also include some empirical formula along with examples which may guide the DISCOMs for finding out the capacitor requirement. 7.2. Based on the above deliberation, CPRI submitted the system study report (enclosed in the agenda of 177th OCC meeting) and which was circulated among all the SLDCs and STUs vide e-mail dated 02.11.2020. 7.3. In the 177thOCC meeting, representatives of Punjab, Rajasthan, Delhi and Haryana stated that the capacitors considered in the study were far less than already installed. In the meeting, it was decided that states shall first analyze the PSSE file considered by CPRI in its study and bring out the locations wherein capacitors are already installed in the network, but are not modelled along with their comments. 7.4. The list of bus-wise available MVAr and the additionally required MVAr computed in the CPRI report was shared separately by NRPC Sectt with SLDCs of Punjab, Haryana, Rajasthan, Delhi and Uttarakhand on 07.01.2021 with the request to provide available MVAr values in those buses. In 179thOCC meeting, it was decided that any submission of MVAr data / feedback from the states would be would be allowed till 22.01.2021 and thereafter CPRI would conduct the modelling and simulation work for the purpose of final capacitor study report. Accordingly, feedbacks received from Punjab, Rajasthan, Haryana and Delhi was forwarded to CPRI for carrying out study and submission of report.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 6 of 38 7.5. CPRI has submitted the revised report on 24.02.2021 and thereafter same was shared with the constituent states. The recommended capacitor compensation, additionally required as per the report is 352MVAr. The report has brought out the additional requirement of 137MVar and 215MVar compensation for Punjab and J&K respectively. Moreover, empirical relationship for capacitor requirement against voltage profile at 11 kV, based on two configurations has been worked out in the report. 7.6. In the 45th TCC / 48th NRPC meeting, it was decided after the submission of report for 2019-20 and the guidelines, the same would be studied by the same Committee who had earlier recommended for guidelines and foreclosure of the contract. Based on Committee’s recommendations, NRPC Sectt. can process the pending bills of Rs. 14 lakhs (Rs. 2 + 12 Lakhs), excluding taxes along with foreclosure of the contract. Accordingly, submitted report needs to be examined by the Committee. 7.7. In the 181st OCC meeting, the sub-group comprising of ten members was advised to study the CPRI report and submit its recommendation within two weeks. 7.8. NRPC Sectt. asked comments/observations on the CPRI report from all the states via e-mail. Comment from Delhi had been received. Rajasthan, HP, Punjab, Haryana had submitted NIL comment. Comment from rest of the members was not received. 7.9. In the 182nd OCC meeting, forum decided that a video-conferencing meeting may be held by members of sub-group to finalize the comments latest by 30th April, 2021 and compiled comments may be sent to CPRI for necessary correction in the report. 7.10. In the 183rd OCC, NRPC representative informed that the meeting of sub-group was held on 03.05.21 (in place of originally schedule meeting on 30.04.21, delayed as per request of some sub-group members due to health related concerns). Representative from Rajasthan could not attend as she was suffering from covid-19 while Uttarakhand representative informed in the meeting that there is an acute shortage of available officers at this time and they will agree to the remarks made by NRLDC. Further, PSSE file was requested from CPRI as per request of all sub-group members for better understanding and the same was shared with them. 7.11. NRPC representative requested for any other comments on the CPRI report, if remaining, from any of the members. Sub-group committee member from Rajasthan stated that since the CPRI report is for the year 2019-20, old data needs to be collected and then values in the CPRI report would be checked. It was further intimated that around 2-3 days time would be required for this task. Rajasthan representative was requested to send their observation/comments via e-mail to NRPC Sectt. at the earliest. 7.12. Forum decided that after receiving observations/comments from Rajasthan, the compiled observations/comments may be sent to CPRI so that necessary corrections may be done in the draft report. 7.13. In 184th OCC, forum was apprised that compiled comments have been mailed to CPRI vide email dated 28th May’21 with a request to submit the corrected report within two weeks’ time. CPRI vide email dated 31st May’21 communicated that majority of comments are on the modeling of base case PSSE file. Since the file is given by NRPC and CPRI has not modeled it; so, they are not in position to make any comment on the accuracy & modeling of file. Forum decided that a reminder may be sent to CPRI for submission of corrected Report as two weeks has already passed.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 7 of 38 7.14. In 185th OCC, NRPC representative intimated the forum that CPRI has submitted its point-wise reply on the observations of sub-group along with updated report on 28th June 2021. 7.15. MS, NRPC expressed concern over inordinate delay in finalizing the report. Forum decided that issues highlighted by the sub-group in the report and clarifications/comments thereon of CPRI need to be converged at the earliest and thus a video-conferencing meeting may be held between the sub-group and CPRI for resolution of issues and enabling report finalization. 7.16. The meeting was held on 06.08.2021 at 11:00 a.m. under the chairmanship of MS, NRPC through Video Conferencing. It was attended by members of the sub-group (constituted for studying the CPRI report), CPRI representatives, and officials from NRPC Sectt & NRLDC. 7.17. In the meeting, comments of the sub-group on the latest version of CPRI report was deliberated in detail. After weighing the merits of the original & both revisions of the report, following were decided: • First Report submitted by CPRI in September, 2020 shall be considered as the reference report. CPRI confirmed that the basecase of 11.07.2018 at 00:45 hrs. received from NRPC Sectt has been used for preparing September, 2020 report. • Comments from all utilities and NRLDC on September 2020 report must be submitted to NRPC Sectt, latest by 24.08.2021. • NRPC Sectt, after examination, shall share with CPRI the compiled comments of the utilities and NRLDC, latest by 31.08.2021. • Thereafter, CPRI shall submit its reply on the compiled comments sent by NRPC Sectt, latest by 15.09.2021. 7.18. Base case file (11.07.2018 00:45 hrs) and CPRI September 2020 report has been e- mailed to all sub-group members on 10.08.2021 requesting to submit comments/observations thereon latest by 24.08.2021 as per decision of the meeting dtd. 06.08.2021. Sub-Committee may kindly note.
8. Automatic Demand Management System 8.1 The status of ADMS implementation in NR, which is mandated in clause 5.4.2 (d) of IEGC by SLDC/SEB/DISCOMs is presented in the following table:
State/ Status Utility
Punjab Scheme not implemented. At SLDC level, remote tripping of 100 feeders at 66 kV is possible. At 11 kV feeder level, ADMS is to be implemented by Distribution Company.
Delhi Fully implemented by TPDDL, BRPL and BYPL. NDMC implementation was scheduled to be completed by
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 8 of 38 State/ Status Utility 31.03.2020 but got delayed due to some changes incorporated in the scheme.
Rajasthan Under implementation. LoA placed on 12.12.2018 with an execution period of 18 months for ADMS at the level of 33 kV feeders at EHV Substation of RVPN under SCADA / EMS part of project. Supply is in progress. Work is under execution and likely to completed by June’2021. ADMS functionality at 11 kV feeders from 33/11 kV substation is under the jurisdiction of the DISCOMs.
UP Scheme implemented by NPCL only. Remote operation of 50 feeders at 132 kV level being operated from SLDC. Further, the solution proposed by M/s Siemens was found to be non- economical and was not accepted by the management. Noida Power Company Ltd have implemented Intelligent Load Shedding (ILS) scheme, in compliance of IEGC requirements for automatic demand management.
Haryana Scheme not implemented. More than 1700 feeders were tested from SLDC control room for remote operation. Regarding the implementation of ADMS at DISCOM level, the matter is being taken up with the DISCOMs.
HP Scheme not implemented. 02 feeders could be operated from SLDC through manual intervention. Letter has been sent by HPSEB to HP-SLDC for making its operation automatic.
8.2 As decided in the 175th OCC meeting, the nominations for matter specific meeting has been received from HVPN, UHBVN/DHBVN, PSPCL, RVPN (SLDC & Automation), UPPTCL, KESCO (DISCOM-UP), NPCL (DISCOM-UP). 8.3 Meetings on ADMS implementation road map have been held with the officers of Haryana, Himachal Pradesh, Punjab and UP on 05.02.2021, 19.02.2021, 05.03.2021, and 14.07.2021 respectively. In these meetings, issues and apprehensions on ADMS were discussed along with vital aspects like addressing the commercial issues, basic architecture for scheme and funding possibilities for the scheme. 8.4 As per request of states for DPR of any state that has got PSDF support for ADMS, website link of PSDF Sectt. has been shared with Haryana, Himachal Pradesh, Punjab and Uttar Pradesh for accessing DPR. Members may kindly note.
9. Follow-up of issues from previous OCC Meetings- Status update. The updated status of agenda items is enclosed at Annexure-A.I.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 9 of 38 All utilities are requested to update the status.
10. NR Islanding Schemes 10.1. Hon’ble Minister of State (IC) for Power and New & Renewable Energy chaired a meeting on 28.12.2020 to review Islanding Schemes in the country. During the meeting following action points, inter-alia, emerged: i. Islanding Schemes shall 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 essential loads should be covered in the Islanding Scheme. 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. iv. All concerned entities to ensure functionality of AUFLS and df/dt relays at all point of time. 10.2. Thereafter, series of meetings were held amongst NR constituents during Apr-Jul’21 to review the existing Islanding Schemes and expedite the implementation of newly proposed Schemes. Special TCC meeting was also held on 15.06.2021, wherein following were decided: a. Delhi: SCADA display work shall be done on priority basis and Delhi SLDC / DTL shall endeavor to complete the work by 31st July 2021. Further, Delhi SLDC was requested to provide updates on Delhi Islanding Scheme to NRPC on fortnightly basis. b. Punjab: Punjab SLDC shall submit status on newly proposed Islanding Schemes to NRPC Sectt on monthly basis. c. Uttar Pradesh: UP SLDC may conduct the required study for freezing the generator and corresponding critical loads for Islanding Scheme(s) within its control area. The tentative timeline for implementing the scheme may be submitted by UP SLDC within a weeks’ time. d. Jammu & Kashmir: J&K representative may consult Delhi DISCOMs (TPDDL / BRPL / BYPL) as they are preparing DPR for load shedding at 11kV or OEMs of R-APDRP project in J&K. Further, J&K to explore the possibility to club the implementation of its Islanding Scheme with the existing R-APDRP projects and in this regard, request may be made to MoP. e. Ladakh: After the submission of feeder-wise data of load centers (Kargil and Ladakh) and historical generation data of Chutak and Nimmo Bazgo HEPs, preliminary study may be done by NRLDC. f. Himachal Pradesh: HP SLDC to firm up all schemes and submit the outcome of studies by 31st July 2021.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 10 of 38 g. Rajasthan: Rajasthan SLDC to put the process for Rajwest Islanding Scheme on fast track and get it implemented before 15 months. Also, Rajasthan SLDC may take up with state regulator for must-run status for the proposed generators for two schemes and submit the Suratgarh study data to NRPC Sectt / NRLDC by 31st July 2021. h. Uttarakhand: Uttarakhand SLDC to submit concrete timelines for implementing Dehradun Islanding Scheme to NRPC Sectt within a month’s time. i. Haryana: Generation pattern of Yamunanagar TPS may be examined by Haryana SLDC. In case, its availability is at least 70%, then same may be considered for Islanding Scheme. Confirmation in this regard along with supporting data may be submitted by Haryana SLDC to NRPC Sectt in a weeks’ time. 10.3. On 29.07.2021, a meeting was taken by Member (GO&D), CEA for reviewing the Islanding Schemes (MoM enclosed as Annexure-A-II). In the meeting, following were decided: a. BYPL to submit their proposal regarding revised critical load to DERC at the earliest. b. Delhi SLDC may seek assistance for system study of the scheme with revised quantum of critical load from CEA/CTU, if required. c. Delhi SLDC to take up the matter urgently with DERC for getting must run status of Dadri-II and APCPL Jhajjar for a conclusive approach d. Implementation of Delhi IS with revised critical load may be expedited. e. Review the Delhi Islanding Scheme on fortnightly basis. f. SOP format (enclosed as Annexure-A-II-A) to be circulated amongst states/utilities so that status of healthiness of relays, communication channel and other equipment of operational Islanding Schemes are submitted to RPC on monthly basis. g. Setting up separate display of Islanding Schemes on SCADA of respective states LDCs and RLDCs for real time monitoring of participating generators & critical loads. h. Explore the possibility of utilizing PSDF fund for Islanding Schemes.
Members may kindly deliberate.
11. Review of availability of ADHPL Transmission system for the month of August & September 2020 11.1 The matter was discussed in 181st OCC meeting. 11.2 In the meeting, NRLDC representative mentioned that ADHEPL took considered decision to delay the outage for transmission line rectification activity till Oct’20 as commercial aspects of ADHEPL’s both generation and transmission were involved. 11.3 It was also discussed that restoration time needs to be within the permissible limits, stipulated in the Standards of Performance of inter-State transmission licensees
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 11 of 38 Regulations 2012. 11.4 ADHEPL representative mentioned that ADHEPL-Nallagarh line evacuates powers of ADHEPL, HPSEB and Kanchanjunga; so non-availability of both circuits of ADHEPL-Nallagarh during peak Hydro month could have affected multiple entities. Further, work execution in hilly terrain during rainy season is an uphill task. 11.5 Views of NR states (beneficiaries of ADHEPL power), on the matter were sought during the meeting. However, in the absence of any response, it was felt by the OCC forum that matter may be deliberated in the upcoming Commercial Sub-Committee meeting so that officers dealing the commercial matters may discuss the issue. Thereafter, matter was taken up in the 43rd Commercial Sub-Committee meeting. 11.6 In 43rd Commercial Sub-Committee meeting, MS, NRPC further stated that considering more than 1600 hours (19:30 Hours on 21.08.2020 to 15:18 Hours on 30.10.2020) outage period due to inclement weather as deemed available has not only financial implications but also would set precedence for other transmission licensees. Therefore, views of all NR beneficiaries may be taken before considering the request of ADHPL. 11.7 It was decided that NRPC Sectt. would seek views of all NR beneficiaries including Kunchenjunga HEP. 11.8 HPSEBL has submitted its views vide letter dtd. 23.07.2021 that action in the matter shall be in line with SPITL Regulation 2012, and review of availability of ADHPL Transmission System shall be denied. (attached as Annexure-A.III). Members may kindly deliberate.
12. Tanda-Basti line (220KV) tripping on unbalanced loading (Agenda by NTPC) 12.1 NTPC has informed vide e-mail dtd. 06.08.2021 that instances of 220KV Tanda-Basti line tripping on Broken Conductor Protection has occurred in recent past. Each time it is observed that there is no actual open conductor fault, instead there is a large, unbalanced loading pattern among 3 phases. Hence, relay senses open conductor protection operating condition (Negative phase sequence component of current above the limit w.r.t. Positive sequence component) and gives trip command, causing 3 pole tripping of breaker at Tanda end. 12.2 This Protection has operated four times in recent past, details of line tripping are given below: Sr. Date Time Current Setting No. 1. 01Oct.2020 15:23:00 I2/I1>0.2,20sec Time delay 2. 17Oct.2020 15:09:00 I2/I1>0.2,20sec Time delay 3. 25June2021 07:58:44 Ir=258.01,Iy=246.18,Ib= I2/I1>0.2,20sec 198.85 Time delay 4. 01Aug.2021 16:51:20 Ir=197.65,Iy=152.78,Ib= I2/I1>0.2,20sec 116.61 Time delay 12.3 In view of importance of this heavily loaded line particularly during peak hours for power evacuation, the issue of 3 phase unbalanced loading needs to be addressed on priority to ensure Grid stability. Detailed trip report dated 01 Aug 2021 is attached
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 12 of 38 as Annexure-A.IV. Members may kindly deliberate. 13. Procedure on Outage Planning for Communication System 13.1 In 184th OCC meeting, draft procedure on Outage Planning for Communication System was discussed. 13.2 Forum decided that all the stakeholders may send their comments on the draft procedure latest by 30th June’21. Thereafter, the draft procedure will be sent to TeST committee for vetting. 13.3 In 185th OCC meeting, NRLDC representative stated that comments would be submitted by 31.07.2021. In view of this, last date for submission of comments by all stakeholders was extended till 31.07.2021. 13.4 No comments have been received till date. Members may kindly deliberate. 14. Keeping 1-Ph ICT unit as spare at BBMB Panipat (Agenda by NR- 2/POWERGRID) 14.1 NR-2 vide email dtd. 10.08.2021 submitted that 400/220/33kV 450MVA ICT-2 consisting of 03 nos. single phase units of 150 MVA at BBMB Panipat was owned by POWERGRID. These units were commissioned in 1985. 14.2 The spare single phase unit belongs to BBMB which was common for ICT-1 and ICT- 2. The detail of transformers at BBMB Panipat are as below:
S.N. Unit identification Ownership Status
T1 ICT-1 R BBMB In service
T2 ICT-1 Y BBMB In service
T3 ICT-1 B BBMB In service
T4 ICT-2 R POWERGRID Now available as spare.
T5 ICT-2 Y POWERGRID Failed on 12.07.2020. Not in Service.
T6 ICT-2 B POWERGRID Failed on 30.06.2018. Not in Service.
T7 Spare Unit BBMB Available
14.3 After failure of above two 1-Ph units of 450 MVA ICT-II bank (POWERGRID owned) at BBMB Panipat, the same were replaced with a 3-ph 500 MVA unit which is in service since 02.10.2020. 14.4 In 174th OCC meeting, it was opined that BBMB would take up the matter for keeping 1-Ph (R-ph unit of ICT-2) unit as a spare with PGCIL management for their 3x150 MVA ICT-1 bank in case of any contingency. 14.5 In this line, matter was taken up with BBMB from POWERGRID side for their view to keep 150 MVA 1-Ph unit as spare for their use. BBMB has intimated to keep that unit as a spare. The letter received from BBMB is attached here with for reference.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 13 of 38 14.6 In view of the above it is proposed to keep 1-Ph unit of (R-ph) ICT-2 at Panipat to be kept as regional spare at Panipat for future utilization till the replacement of 450 MVA ICT-1 bank by BBMB. Members may kindly deliberate. 15. Time Extension of OCC approved Shutdown availed for Construction Works (Agenda by NR-3/POWERGRID) 15.1 NR-3 vide email dtd. 11.08.2021 has submitted that the approval for Shutdown of Grid Elements to facilitate Construction related works and maintenance activities are got approved in OCC and allowed by NRLDC as per Outage Planning Procedure of NR. The planning for such Shutdown is done months ahead with estimation of available data and resources on tentative basis only, which is further dependent upon any unforeseen circumstances, prevailing system and site constraints during real time work execution. 15.2 In this context it is worth to mention here that POWERGRID always make its best efforts to complete the scheduled work in stipulated/approved time period with minimum possible deviation however in some of the major construction related works of new integration, Renovation/ upgradation etc., duly approved by CERC/RPC, it is not possible due to unforeseen circumstances at site, Change of Weather and ROW issues, statutory clearances, non-availability of OEM engineer/ T&P & test kit etc. 15.3 Even after completion of commissioning activities and readiness to charging, there may be delay due to pending statutory and RLDC clearances. To add on, Global health impact and hurdles caused by COVID-19 pandemic and Govt. restrictions have been badly affecting the work output. As a matter of fact, the outage period may vary on case to case basis depending upon real time constraints, which is beyond control of any utility/ transmission licensee and cannot be exactly predicted. It is also understood that any transmission element under outage cannot be restored until confirming its complete readiness. 15.4 Few cases are as follows:
Sl. No. OCC Name of Approved Outage Actual Remarks No. Elements Period Outage Period
1 Vindhyachal 04.06.21 to 17.06.21 04.06.21 to Due to 183 Block-1 25.06.21 Covid-19 situation and FTC formalities
2 183 400 KV 04.06.21 to 17.06.21 04.06.21 to Due to Vindhyachal- 21.06.21 Covid-19 Singrauli 1& 2 situation
3 183 400 KV 04.06.21 to 17.06.21 04.06.21 to Due to Vindhyachal- 21.06.21 Covid-19 Vindhyachal(Fe situation eder) 1& 2
4 184 400 KV Orai- 26.07.21 to 29.07.21 26.07.21 to Due to bad Orai 1 & 2 11.08.21 weather and (Tentative) continuous
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 14 of 38 Sl. No. OCC Name of Approved Outage Actual Remarks No. Elements Period Outage Period rain at site
15.5 In view of above laid facts, approval for extension of these shutdown may please be concurred by OCC. Further such extension in OCC approved outages, related to construction work, for more than a day, may be brought for concurrence in next OCC meeting however, request/ information for such extension is conveyed to NRLDC in advance at earliest possible as per provision of NRPC approved Outage Planning procedure and any deviation/ extension for less than a day shall be considered to be allowed accordingly. Members may kindly deliberate. 16. Follow up with reference to discussion held in 10th NPC Meeting 10th NPC Meeting was held on 09th April 2021, wherein status on following points has been discussed: a) Submission of the feeder mapping data. b) Submission of AGC implementation data. c) Monitoring for implementation of the sanctioned projects under PSDF. Members may kindly update the status.
खण्ड-ख: उ.क्षे.वि.स. Part-B: NRLDC
17. Revision of Operating Procedure document of Northern Region 2020-21 In 185th OCC meeting, NRLDC representative stated that after requesting comments from utilities in 184th OCC meeting, the document “Operating procedure of Northern region” has been revised. Major changes in the document were presented in the meeting and some of the changes were discussed in detail.
After some of the utilities raised apprehensions regarding changes in point 3.2(b), point 4.4 (iii) and point 4.4(viii), constituents were asked to send their comments on Operating Procedure document available on NRLDC website to NRPC/NRLDC within 10 days. Based on views received from constituents, NRPC would develop the common opinion and accordingly the views would be discussed in next OCC meeting.
The comments received by NRPC/NRLDC are attached as Annexure-B.I.
Members are requested to deliberate on the comments received and further discuss if any modification is required in Operating procedure document.
Moreover, utilities have been requested number of times to update list of radial feeders which can be opened on the directions of NRLDC to regulate the demand. List of such radial feeders has been provided by respective utilities and is part of ‘Operating Procedure of Northern Region’. Latest updated document is available at https://nrldc.in/download/operating-procedure-of-northern-region-for-2017-18- 2/?wpdmdl=8251. Following are the attributes for such feeders:
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 15 of 38 • Feeders shall be radial in nature • They should usually have substantial load flow so that reduction of drawal can be prominently noticed on opening of such lines.
It is also important that it is duly verified by SLDCs that the list of feeders is actually radial in nature and is likely to provide the expected relief when such feeders are opened. If such feeders are part of any other scheme such as any SPS, UFR or df/dt, same may also be mentioned.
List of radial feeders have been received from Rajasthan SLDC and Punjab SLDC, they are requested to provide above mentioned information also. Even after repeated requests, the respective information is pending from many utilities.
The opening of feeders is generally an extreme step which shall be required in case of threat to grid security and non-adherence to RLDC instructions to manage overdrawl by SLDCs/ DISCOMs. In such a case, every utility needs to take actions to support RLDC by following their instructions including opening of feeders. The priority for opening of feeders in case of sustained over drawl by a constituent should remain as:
• Radial feeders identified (also part of Operating procedure) • Intra-state ICTs such that it does not impact the interstate transmission system and provides load relief without effecting power supply to important establishments/ feeders • Interstate lines/ICTs i.e. connected to one or more ISTS substation. Utilities may also intimate in case no radial feeders are available to disconnect. In such a case, NRLDC along with constituent will study the grid connected feeders /ICTs for disconnection which has low impact in the NR Grid. For such states, it is requested to nominate one nodal officer from SLDC which shall coordinate with NRLDC and study about such feeders. Apart from this, states are advised to take remedial measures for minimizing sustained over drawal at low frequencies as per the IEGC. Also, telemetry is to be ensured for all such feeders for monitoring in real time by SLDC/ NRLDC. Member may like to deliberate. 18. Computation of TTC/ATC of respective control areas In last several OCC meetings, NRLDC had shared monthly ATC/TTC limits of NR control areas, worked out by respective SLDCs in coordination with NRLDC. Need for involvement of SLDC officials in ATC/TTC assessment has also been deliberated number of times. As per section4 of the detailed procedure approved by CERC, for relieving congestion in real time it is the responsibility of SLDCs to assess their ATC/TTC and get it vetted by NRLDC. To facilitate the same, NRLDC has also conducted many workshops and Video Conferences over the last few years.
Most of the NR states except Uttarakhand and J&K are sharing basecase and ATC/TTC assessment with NRLDC. ATC/TTC assessed by SLDCs in coordination with NRLDC and reliability issues expected for the upcoming months are mentioned below. SLDCs are requested to go through the tentative ATC/TTC limits for September 2021 (Annexure-B.II) and provide comments.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 16 of 38 Reliability issues faced/ expected for next few months are highlighted below:
Punjab: ATC/TTC of Punjab state control area was assessed as 6800/7400MW. However, it was revised on several occasions in June and July 2021 due to outage of TalwandiSaboo generating units. Punjab has also implemented SPS at Nakodar which has helped in enhancing ATC/TTC limits of Punjab. Punjab SLDC has informed that working hours of general industries in Nakodar, Gobindgarh(Rajpura) and Ludhiana area is 9am-6pm. Therefore, loading is lower in these area during night hours. Moreover, solar power from Bikaner is also not available at Moga during non-solar hours. Accordingly, higher ATC/TTC limits during these hours were approved. Presently ATC/TTC limit of 7300/7900 MW and 7700/8300MW have been declared till 31st Aug due to forced outage of Talwandi Saboo Unit-1. Plots showing ATC and N-1 violations at 400/220kV Rajpura, Nakodar, Moga and Ludhiana ICTs are attached in Annexure-B.III. Punjab SLDC is requested to ensure high generation at 220kV level during high demand, which would help in meeting high demand & also improve voltage profile. Loading of 400/220kV ICTs may also be ensured within their N-1 contingency limit. UP: ATC/TTC assessed by UP SLDC in coordination with NRLDC is: State TTC ATC Gen
11000 13800 13200 11500 13500 12900 12000 13300 12700 Loading above N-1 contingency limits were observed at 400/220kV Azamgarh, Allahabad(PG), Sarnath, Gorakhpur(UP), Sohawal(PG), Lucknow(PG) ICTs. UP SLDC is requested to ensure high intra-state generation during high demand, which would help in meeting high demand & also improve voltage profile. It is also requested to ensure loading at 400/220kV ICTs within their N-1 contingency limit.
Evacuation constraint at Bara and Meja: Connectivity of Bara and Meja generating stations was presented in 185 OCC meeting:
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 17 of 38
In 185th OCC meeting, the connectivity of Bara and Meja was described. It was highlighted that 400kV Meja-Allahabad (Twin Moose) line was observed to be highly loaded on several occasions during last few weeks. Under N-1 contingency of one line, the loading of other line is expected to reach beyond 900MW. Thus, there is need to carry out detailed simulation studies for different scenarios and suggest remedial measures. As per preliminary studies done by NRLDC, it was suggested that loading of 400kV Meja-Allahabad D/c may be restricted to 520MW on each ckt to ensure N-1 compliance. Moreover, there is significant impact of Singrauli generation. Due to outage of units/less generation at Singrauli, the loading from Meja to Allahabad would increase. Studies attached as Annexure-I of 185 OCC minutes. It was also discussed that issue is likely to aggravate with commissioning of 765/400kV ICT-2 at Bara. UP SLDC was asked to carry out studies and suggest requirement of SPS scheme. Already implemented SPS at Bara may also be included while designing the SPS and suggesting safe loading of 400kV Meja-Allahabad. UP SLDC may update/ share the studies as agreed in 185 OCC meeting. Haryana: Haryana SLDC had shared revised studies for ATC/TTC assessment after meeting held on 7th July 2021 with UHBVN, Haryana SLDC, NRPC and NRLDC to discuss issues related to import capability of Haryana state control area. Subsequently, NRLDC has shared its observations on 13th July 2021. 400/220kV ICTs (2*315 MVA) at Deepalpur(HVPNL) are still N-1 non-compliant under N-1 contingency, loading of other ICT would go up to 124%(As per the basecase shared), which is not desirable. In real time operation also ICTs at Deepalpur and Kurukshetra(PG) violate N-1 loading limit. Without any arrangement (SPS/Significant Load management/ICT augmentation) at Deepalpur(HVPNL) and Kurukshetra, it may not be possible to enhance the TTC/ATC limit.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 18 of 38 N-1 violations at 400/220kV Deepalpur and Kurukshetra ICTs are attached as Annexure-B.III. Haryana SLDC is once again requested to implement SPS at 400/220kV Deepalpur and Kurukshetra (PG) and carry out load management at Sonepat and Panipat to enhance their ATC/TTC limits at the earliest. Delhi: Delhi SLDC have assessed ATC/TTC limits as 6500/6800 MW and had shared results with NRPC as well as NRLDC. Constraints observed in assessment by Delhi SLDC are at, 400/220kV Bamnauli and Mundka ICTs. Due to radial feeding of load from most of the stations, reliability is reduced and requirement of SPS may be explored by Delhi SLDC to avoid complete load loss as was seen in few events in July 2021. With SPS, loss of power supply to critical loads such as DMRC may be avoided. Moreover, Delhi SLDC is advised to display ATC/TTC limits on their website. As of now only violations of ATC/TTC are being displayed on Delhi SLDC website. Rajasthan: Revised ATC/TTC figures have been shared with NRLDC for Jul-Aug 2021 and are as: State TTC ATC Gen
8200 6200 5900 4100 8100 7800
Rajasthan SLDC is requested to take up the matter for implementation of SPS at Jodhpur and other stations with STU and ensure loading below N-1 contingency limit at constrained 400/220kV ICTs. Moreover, ATC/TTC assessed for states such as HP, Uttarakhand, J&K and Ladakh U/T is shown below: TTC RM( State ATC( State (M MW Limting constraint Generation MW) W) ) J&K and 170 N-1 contingency of 400/220kV Low Hydro 150 1550 Ladakh 0 Amargarh ICTs N-1 contingency of 400/220kV 120 HP Low Hydro 100 1100 Nallagarh ICTs and 220kV 0 Nallagarh-Uperanangal D/C Uttarakh 160 N-1 contingency of 400/220kV Low Hydro 100 1500 and 0 Dehradun and Kashipur ICTs
As discussed in last several OCC meetings, all SLDCs need to furnish ATC/TTC details of their control area at respective SLDC websites. Now, it is being observed that most of the SLDCs except Uttarakhand, J&K and Delhi (real-time violation available) are uploading ATC/TTC limits on their websites.
SLDC Link for ATC on website https://www.upsldc.org/documents/20182/0/ttc_atc_24-11- UP 16/4c79978e-35f2-4aef-8c0f-7f30d878dbde Punjab https://www.punjabsldc.org/downloads/ATC-TTC0321.pdf Haryana https://hvpn.org.in/#/atcttc Delhi NA (real-time violation reporting available) Rajasthan https://sldc.rajasthan.gov.in/rrvpnl/scheduling/downloads HP https://hpsldc.com/mrm_category/ttc-atc-report/ Uttarakhand NA
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 19 of 38 J&K and Ladakh U/T NA
J&K and Ladakh U/Ts and Uttarakhand are once again requested to advise the concerned officers to evaluate their ATC/TTC limits in coordination with NRLDC and share latest assessment with NRLDC and NRPC. Plots suggesting N-1 non-compliance at several 400/220kV ICTs is attached as Annexure-B.III. It is again requested that SLDCs may ensure that loading of ICTs and lines are below their N-1 contingency limits.
All SLDCs are requested to share basecase as well as ATC/TTC assessment with NRLDC/NRPC on monthly basis as well as upload on their websites. Members may like to discuss.
19. Grid operation related issues (i) SPS Implementation at Bhadla (PG)
The SPS logic decided in the 45th TCC meeting and approved in the 48th NRPC meeting was explained to OCC members in 181 OCC meeting. POWERGRID representative had intimated that QR for the SPS tender has already been finalized and NIT may be floated within next two weeks In 183 OCC meeting, POWERGRID representative stated that presently QR has been approved and tender documents are being prepared by C&M department. It is expected that the work is likely to awarded by June end. OCC expressed concern on the slow progress and asked POWERGRID to expedite the work in view of increasing solar generation and importance of SPS in the complex. NRLDC representative also highlighted the importance of SPS in the complex and asked POWERGRID to expedite the work as it is pending since long. POWERGRID may kindly share the latest status with OCC forum. (ii) Schedule >ATC for state control areas
ATC/TTC assessment exercise for respective state control area is being carried out by SLDCs in coordination with NRLDC. Some of the states are also publishing ATC/TTC limits on their website. ATC limits suggest that there are likely n-1 violations in system if import of state is close to or higher than ATC limits. These constraints are also mentioned in ATC/TTC assessment reports of SLDC/ NRLDC. However, it is being observed that Haryana is scheduling power beyond the ATC limits assessed by SLDCs/NRLDC which should not be carried out.
Details shown below.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 20 of 38 ATC limit
As discussed in last OCC meeting:
• NRLDC will be monitoring the TTC/ATC in real time operations and accordingly messages will be issued to constituents to restrict the drawal as per TTC/ATC. • Core simulation studies team may be constituted at regional level and they should regularly meet quarterly to assess the vulnerabilities in the grid. • If no constraint are being observed when drawl crosses ATC limit, same may be duly intimated to studies team of SLDC/ NRLDC so that ATC/TTC limits are accordingly revised.
In view of increasing renewable penetration and grid complexity, it becomes important that utilities regularly assess their import capability limits and try to ensure their drawl within this limit. This shall help in ensuring safe and secure grid operation at state as well as regional level.
SLDCs are requested to ensure that the net power scheduled by them considering all long term, medium term and short term contracts remain strictly within their ATC limits for all time blocks of the day so that system operates in safe and secure manner.
Members may like to discuss.
(iii) Performance of Grid connected RE plants
In view of India’s target of achieving 175GW renewable capacity by 2022, the commissioning of RE plants has picked up pace in last several months. However, during providing clearance for first time charging of these RE plants and during real- time grid operation, some major challenges are being faced.
Number of RE plants are planned and are being commissioned. These RE plants seeking registration at NRLDC submit their Plant model as per the first time charging procedure. Model is tested and validated at NRLDC end to check whether Plant can meet the CEA compliances as per the Central Electricity Authority (Technical Standards for Connectivity to the Grid) (Amendment) Regulations, 2019. However, while analyzing the Capability curve of some of the Plants at POI drawn using PSSE
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 21 of 38 model/case, it has been observed that plant won’t be able to deliver required MVAR when generating its rated MW capacity. However temperature also plays important role is RE generation, for reference inverter temperature de-rating curve is present below.
Capability curve of such a sample Plant is shown below.
Reactive power capability curve of 300 MW plant shows how it is meeting CEA compliance at 40◦C but not meeting CEA compliance at 50◦C.
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 22 of 38
RE plants have a common characteristic that if they generate their maximum power (MW) they need sufficient amount of reactive power for their inverter and other equipment. RE plants generally operate in Power factor control mode in order to meet the CEA compliance and to maintain the power factor within the limits of 0.95 lagging to 0.95 leading at POI. Extra MVAR that RE plants need when they generate Max MW is absorbed from the grid by the RE plant at POI. (Examples from Real time operation is demonstrated for solar connected at Bhadla(PG) and Wind at Akal). (Example of ACME solar is taken and wind at Akal is taken)
P(MW) & Q(MVAR) of 250 MW ACME solar. (P(MW) & Q(MVAR) of 220kV Bhadla(PG)-ACME line, connected at Bhadla (PG (ISTS POI) is considered).
220kV bus voltage at Bhadla(PG) and Q(MVAR) of 250 MW ACME solar. (Q(MVAR) of 220kV Bhadla(PG)-ACME line, connected at Bhadla (PG (ISTS POI) is considered).
बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 23 of 38 The above two plots of ACME solar shows that 250 MW ACME solar. injecting around 230-240 MW at the time of its peak solar generation and absorbing around 42-45 MVAR at ISTS POI (Bhadla(PG)), while 220kV bus voltage at Bhadla(PG) is around 205kV-210kV.
Considering above following is proposed for discussion:
• As per CEA regulations and grid requirements, it is required that plant should not be a liability to grid, and just inject quality power of having pf (0.95lag • Plant to operate in Voltage control mode, such that voltage at ISTS POI won’t degrade. Member may like to discuss. Similarly, the issue of LVRT non-compliance of wind generators has also been discussed in several OCC meetings. In 184th OCC meeting, it was discussed that: • Rajasthan SLDC representative informed that proposal for PSDF funding for ensuring LVRT compliance in old plants is under process as per orders from higher management. In this regard, cost estimates are being taken from old wind generators. However, estimates are being received only from some of the wind generators. • Separate meeting may be called with all wind developers in Rajasthan and participants from NRPC, NRLDC, Rajasthan SLDC so that all issues related to wind generators including LVRT non-compliance etc. may be discussed and resolved • Certificate may be obtained from wind generator that turbine is LVRT compliant as per regulatory requirements. Moreover, it becomes important that during fault events, LVRT compliance is checked at SLDC level. बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 24 of 38 Wind generation connected to 400kV Akal(RRVPNL) (Total MW and MVAR of all four ICTs is considered) 400kV bus voltage at Akal(RRVPNL) and Q(MVAR) coming from 220kV side at Akal (Total MVAR of all four ICTs is considered) As per latest information available with NRLDC, following is status of LVRT compliance of wind generators in Rajasthan: Total LVRT Total Non with without compliant LVRT OEM Name / WTG LVRT LVRT LVRT commissione compliant compliant complian complian d Capacity commissioned t t (MW) Capacity (MW) Siemens Gamesa 148 90 296 76.5 Regen Power Tech. Pvt. 151 226.5 Ltd Vish Wind (India) Ltd. 12 1308 7.2 994.81 (Former Wind World) बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 25 of 38 Suzlon Energy Ltd. 343 975 534.95 1411.8 GE India Industrial Pvt. 93 154.1 Ltd. Inox Wind Ltd. 286 572 Rajasthan SLDC may update on progress for ensuring LVRT compliance of WTGs. Also measures being taken to manage reactive power drawl at Akal and minimizing low voltages in the area. Members may like to discuss. (iv) Long outage of transmission elements/ generating units Reasons and revival date for elements under long outage are being discussed regularly in OCC meetings. Any update on the status of these elements from last OCC meeting may be shared with the forum (Annexure-B.IV). All utilities are requested to make it a practice to update status of elements under long outage in the NRLDC outage software portal. Utilities are requested to take necessary actions to revive elements which are under long outage. (v) Maintaining frequency profile of the grid In last several OCC meetings, SLDCs were asked to take necessary actions to minimize large fluctuations during real-time. In 181st OCC meeting, it was deliberated that some improvement was seen in frequency profile and excursions were reduced in last month, however there is still need for significant improvement in load changeover and primary frequency response from generators. Still frequency excursion can be observed which need to be further minimized. UP representative stated that they are regularly taking up the matter for primary frequency response from generators after every event. State generators have been asked to conduct primary frequency response testing. Initiatives are also being taken to minimise sudden load change at hourly boundaries. Punjab representative informed that performance of generators is being monitored regularly and quarterly reports are being sent to SERC. The primary frequency response of generators under Punjab state control area has improved over the years. In 182 OCC meeting, UP SLDC representative stated that they are trying to stagger supply hours such that some areas are provided supply five minutes before or after block change so as to minimize the change in demand during hourly/ block boundary. Apart from this, they are regularly taking up the matter for primary frequency response from generators after every event. In spite of such persuasion, it is observed that there are frequency excursions especially at hourly boundaries. Moreover, on several occasions continuous low frequency operation was observed. To minimize this, as has been requested many times, all utilities shall try and ensure maximum possible intrastate generation. बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 26 of 38 Frequency profile for 09.08.2021 showing hourly excursions Frequency profile for 07.08.2021 showing continuous low frequency operation NR Constituents are once again requested to take initiatives to minimise sudden load changeovers at hourly boundaries and also monitor performance of generators under their jurisdiction when the frequency is having large excursions. Following necessary actions may be taken to minimize frequency excursions during real-time: • Improving accuracy of load forecasting बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 27 of 38 • Backing down intra-state generation • Buying/ Selling power in real-time market • Surrendering/ Requesting ISGS power timely • Avoiding manual opening of feeders in coordination with DISCOMs Moreover, RGMO/FGMO shall be ensured in service by advising all state owned and intra- state generators and their compliance needs to be monitored and taken up with SERC if required in addition to staggering of loads. Members may like to discuss. 20. Frequent forced outages of transmission elements in the month of July’21: The following transmission elements were frequently under forced outages during the month of July’’21: No. of forced S. NO. Element Name Utility/SLDC outages 1 400 KV Bareilly-Meerut (PG) Ckt-1 3 POWERGRID 2 400 KV Orai-Mainpuri (UP) Ckt-2 3 UP 400/220 kV 240 MVA ICT 3 at 3 3 UP Obra_B(UP) 220 KV Amargarh(NRSS XXIX)- 4 5 NRSS XXIX/ JK Ziankote(JK) (PDD JK) Ckt-2* 220 KV Singoli 5 Bhatwari(Singoli(LTUHP))- 4 Uttarakhand Srinagar(UK) (PTCUL) Ckt-1** 220 KV Singoli 6 Bhatwari(Singoli(LTUHP))- 4 Uttarakhand Srinagar(UK) (PTCUL) Ckt-2 220 KV Saharanpur(PG)-Shamli(UP) 7 4 UP/POWERGRID (UP) Ckt-1 *- Tripped frequently in June’21 also. ** Tripped frequently in April’21 also. The complete details are attached at Annexure-B.V. Frequent outages of such elements affect the reliability and security of the grid. Hence, utilities are requested to analyse the root cause of the tripping and share the remedial measures taken/being taken in this respect. Members may like to discuss. 21. Multiple element tripping events in Northern region in the month of July’21: बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 28 of 38 A total of 26 grid events occurred in the month of July’21 of which 20 are of GD-1 category. The preliminary report of all the events have been issued from NRLDC. A list of all these events along with the status of details received by 05-August-2021 is attached at Annexure-B.VI. Further, despite persistent discussions/follow-up in various OCC/PCC meetings, the compliance of the regulations is still much below the desired level. Maximum Fault Duration is 2840ms in the event of multiple element tripping at 400/220 kV Bareilly (UP)on 23-July-21 at 16:36hrs. Delayed clearance of fault (more than 100ms for 400kV and 160ms for 220kV system) observed in total 11 events out of 26 grid events occurred in the month. In 8number of events, fault signature couldn’t be captured from PMU data. Members may take necessary preventive measures to avoid such grid incidents / disturbances in future and discuss the same. Moreover, utilities may impress upon all concerned for providing the Preliminary Report, DR/EL & Detailed Report of the events in line with the regulations. Members may like to discuss. 22. Details of tripping of Inter-Regional lines from Northern Region for July’21: A total of 4 inter-regional lines tripping occurred in the month of July’21. The list is attached at Annexure-B.VII. Out of 4 number of tripping’s, 4 tripping incidents are related to HVDC system. The status of receipt of preliminary reports, DR/EL within 24hrs of the event and fault clearing time as per PMU data has also been mentioned in the table. The non-receipt of DR/EL & preliminary report within 24hrs of the event is in violation of various regulations. As per regulations, all the utilities shall furnish the DR/EL, flag details & preliminary report to RLDC/RPC within 24hrs of the event. They shall also furnish the detailed investigation report within 7 days of the event if fault clearance time is higher than mandated by CEA (Grid Standard) Regulations. Members may please note and advise the concerned for taking corrective action to avoid such tripping as well as timely submission of the information. 23. Status of submission of DR/EL and tripping report of utilities for the month of July’21. The status of receipt of DR/EL and tripping report of utilities for the month of July 2021 is attached at Annexure-B.VIII. It is to be noted that as per the IEGC provision under clause 5.2 (r), detailed tripping report along with DR & EL has to be furnished within 24 hrs of the occurrence of the event. However, it is evident from the submitted data that reporting status is not satisfactory and needs improvement. Also, it is observed that reporting status has been improved from CPCC3, Delhi, HP and Haryana in May, 2021 compared to the previous month. Members may please note and advise the concerned for timely submission of the information. It is requested that DR/EL of all the trippings shall be uploaded on Web Based Tripping Monitoring System “http://103.7.128.184/Account/Login.aspx” बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 29 of 38 within 24 hours of the events as per IEGC clause 5.2.r and clause 15.3 of CEA grid standard. Apart from prints of DR outputs, the corresponding COMTRADE files may please also be submitted in tripping portal / through email. 24. Frequency response characteristic: Two FRC based event has occurred in the month of July-2021. Description of the event is as given below: Table: Starting End S. Event Time Event Description Frequency Frequency Δf No. Date (in hrs.) (in Hz) (in Hz) On 20th July 20201 at 10:25 hrs, As reported 220 KV Akal-Dangri (RS) Ckt- 1 & Ckt-2 tripped on R-Y phase to phase fault. Fault distance was 174meter 20- and fault current was 1 July- 10:25hrs 50.07 50.01 -0.06 18.14kA from Akal end. 21 During the event, Rajasthan wind generation loss of approximately 1550MW is observed i. (as observed from SCADA data). On 22nd July 2021 tripping of 400kV UPCL- Hassan-1 on R-N Fault and 400kV UPCL- Hassan-2 on Y-N fault was reported at 15:05 and 22- 15:08 Hrs respectively. 2 July- 15:08hrs During the event, 49.99 49.94 -0.05 21 generation loss of 1400MW occurred in Southern Region, due to Unit tripping on SPS operation at UPCL (Units 1 & 2) and VARAHI Hydro (Units 1,2,3 & 4). The Hon’ble CERC approved procedure has already been shared with all concerned during previous OCC meetings. FRC observed for each state control area for the events is tabulated below: बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 30 of 38 FRC calculation of ISGS stations based on NRLDC SCADA data is tabulated below: बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 31 of 38 FRC calculation of major state generators based on NRLDC SCADA data is tabulated below: बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 32 of 38 In line with the decisions taken during various OCC meetings, the time and date of the FRC events were e-mailed to respective utilities. Constituents may submit the FRC of their control areas for the above event and reason of poor response, if observed. बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 33 of 38 For event on 20th July, 2021, FRC information has been received from AD Hydro, Kawai, Koteshwar, Harduaganj, NHPC, NJPC, Rihand, Singrauli, Tanda, Unchahar, Rosa TPS & UP control area. For event on 22nd July, 2021, FRC information has been received from AD Hydro, Kawai, Koteshwar, NHPC, Rihand, Singrauli, Talwandi sabo, Unchahar, Rosa TPS & UP control area. Other utilities are also requested to kindly share the FRC calculations and further action taken at their end. 25. Status of PSS tuning/ re-tuning and Step Response Test of generator Maintaining properly tuned Power System Stabilizers in service is essential for damping of inter area and local mode of oscillations in the grid. As we all know, Indian electricity grid is continuously expanding and lots of Power Electronics devices were also commissioned in recent years changing the dynamics of grid. As possibility of development of power oscillations under certain operating conditions cannot be ruled out, PS S tuning /re-tuning is required for damping of oscillations. In this regard one committee at NRPC level was formed in year 2014 and it was agreed that If results of Step Response Test on concerned grid connected generators indicate sufficient damping, generating company would perform next Step Test after three year or at the time of major overhauling of the machine, whichever will be earlier and Generating Companies would arrange for re-tuning of PSS, if Step Response Test indicates insufficient damping of oscillations. In 180th, 181st, 182nd, 183rd, 184th & 185th OCC meeting, this point was discussed and Utilities were requested to submit the present status of PSS tuning/re-tuning and Step Response Test of their respective generators as per the below mentioned format. Date of last PSS Date of last Step tuning / re- Report Name of the Response Test S. tuning submitted Remarks Generating performed (in No. performed (in to NRLDC (if any) Station DD/MM/YYYY DD/MM/YYYY format ) (Yes/ No) format ) Status report in above format updated till 08thAugust 2021is attached as Annexure- B.IX. It may be noted that except Anpara-A U-3, Parichha-C U-5, Baspa U-2, Unchahar-II U- 1, Jhakri U-1&3, all units of Tehri and Koteshwar, and all units of Rampur HPS, PSS of other major units were last tuned several years ago. Therefore, once again all utilities are requested to arrange exciter step-response test or tuning of their respective units बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 34 of 38 and submit the report of PSS tuning/ re-tuning/ Step Response Test through email to NRPC and NRLDC at [email protected] and [email protected] respectively. Members may kindly accord due priority in this regard and update about their future plan for PSS tuning as there is no progress despite including this agenda in every OCC meeting. 26. Frequent multiple element tripping at 400kV Muzaffarnagar(UP), 400kV Alaknanda(UP) & 400kV Vishnuprayag(UP) complex: Two major grid events of multiple element tripping at 400kV Muzaffarnagar(UP), 400kV Alaknanda(UP) & 400kV Vishnuprayag(UP) complex occurred recently which led to generation loss of approximately 850MW in Alaknanda HEP, Vishnuprayag HEP & Singoli Bhatwari generation complex. a) In first incident at 14:39 Hrs on 20 Jul 2021, 400kV Alaknanda-Muzaffarnagar Ckt tripped on Y-N phase to earth fault, and no attempt forauto-reclosing was observed. Further, 400KV Muzaffarnagar (UP)-Vishnuprayag (JP) (UP) Ckt tripped on over current protection operation at Vishnuprayag end. Due to tripping of both evacuating lines, all the Units of Alaknanda HEP, Vishnuprayag HEP & Singoli Bhatwari (SINGOLI) tripped leading to generation loss of approximately 850MW. As per NR protection philosophy, over current protection should not be enabled in 400kV lines. SLDC-UP may ensure the disabling of over current protection at Vishnuprayag end. Further,Auto-recloser operation during Line to ground fault in 400kV Alaknanda-Muzaffarnagar is to be ensured by UPPTCL b) In thesecond incident at 03:02 Hrs on 07 Aug 2021, 400/220kV 315 MVA ICT 3 at Muzaffarnagar (UP) tripped on differential protection operation on blastingof R-ph CT of ICT 3, which was connected to Bus 2. At the same time, bus bar 1 protection operated which resultedinto tripping of ICT 1, ICT 4, 400kV lines to Meerut, Ataur and Vishnuprayag which were connected to Bus 1. Further, 400kV Alaknanda-Muzaffarnagar Ckt-1 also tripped on B-N phase to earth fault on B-ph CT damaged at MuzaffarnagarS/s. Due to tripping of evacuating lines all the units ofAlaknanda HEP, Vishnuprayag HEP and Singoli Bhatwari tripped leadingto generation loss of approximately 850MW. As per PMU, R-N & B-N fault followed by Y-N fault observed with delayed clearance in 760ms. SLDC-UP may share the details regarding exact nature of fault, reason of operation of bus bar-1 (as fault was in ICT 3, which was connected to bus 2), reason of tripping 400kV Muzaffarnagar-Alaknanda Ckt. The list of all the tripped elements andthe PMU plots of phase voltages for all aforementioned incidents are attached as Annexure-B.X. Such delayed clearance of fault, non-operation of auto-recloser during line to ground fault and sensitive protection setting may lead to multiple elements tripping and such incidents in generation complex area lead to sudden significant generation loss, which affect the reliability and security of the grid. Therefore, it is requested that the events may be analyzed in detail and shortcomings in the operation and protection system may be immediately resolved. A confirmation of the actions taken along with detailed report may please be submitted to NRLDC/ NRPC. बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 35 of 38 Members may like to discuss. 27. Non-Availability / Reliability of Telemetry In order to have proper visualization and Situational awareness to control room operator for ensuring reliable grid operation, uninterrupted availability of telemetry is essential. It is essential to ensure 100% availability of the data from all the Sub-stations. However, it is seen that data is highly intermittent even for some of the 400kV/ 765kV Sub-stations. The non-availability of various 400 KV / 765 stations was calculated for the month of June 2021. The list of stations where data availability is less than 95% is given below. Central Sector UPPTCL RRVPNL Shree Cement Parichha Heerapura Bairaisuil Noida Sec-148 Alwar AD Hydro Rosa Kalisindh Karcham Wangtoo Muradnagar Bhainsara Parbati-2 Meja Hindaun Parbati-3 Bara Rajwest DTL PTCUL Hindaun CCGTB Srinagar SSCTPS HPSEBL Anta HVPNL WANGTU Nuhiyawali Kirori *Intermittency based on June’2021-month data availability Telemetry of digital status The importance of correct Digital telemetry was discussed in all the TeST sub- committee meeting and it is observed that there is no improvement in this regard. It is was decided in previous TeST Sub-committee meeting that the constituent will furnish the availability status of 220 kV and above stations and improvement there off. Availability of digital status based on snapshot of 2nd Aug 2021 (1100 hrs) is given below: Total Available Not Available % Availability PGCIL 3468 3359 109 96.86% UPPTCL 2377 1563 814 65.76% RRVPNL 2021 1449 572 71.70% PSTCL 868 586 282 67.51% HVPNL 769 642 127 83.49% JKPDD 156 7 149 4.49% PTCUL 174 124 50 71.26% HPSEBL 156 125 31 80.13% BBMB 261 233 28 89.27% DTL 617 531 86 86.06% बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 36 of 38 Matter has been taken up with various constituents through letter / meetings for improvement of telemetry. It is requested to take up for improvement of telemetry for better system visualization and grid Operation. The matter was also discussed in 18th TeST Meeting, wherein representative from SLDCs informed that they have been taking up the telemetry issue with transmission wing for improvement of telemetry. All concerned are requested to take up the issues on priority. Member may like to discuss the issues and resolution target for restoration of reliability. 28. Multiple elements tripping at 220kV NAPP(NP) on 11th August 2021 at 1335Hrs. Grid event of multiple element tripping occurred at 220kV NAPP (NP) on 11th August 2021 at 1335Hrs, which led to generation loss of approximately 365MW in Narora Power plant and poisoning out of both the units. As reported, R-ph CVT of 220kV NAPP-Sambhal Ckt got burst at NAPP, which converted into R-Y phase to phase fault. 220kV lines to Sambhal, Khurja, Atrauli, Simbholi and Debai all tripped from remote end in zone 2 (Z-2) and from NAPP end in main protection operation. At the same time, NAPP Unit 1 tripped on Class A (Over fluxing stage- 2) protection operation. After 20sec, NAPP Unit 2 tripped on over frequency protection operation as frequency rose up to 51.5Hz for 20sec. As per PMU, R-Y phase to phase fault is observed. As per SCADA, generation loss of approx. 365MW is observed at NAPP. In antecedent condition, 220kV lines to Sambhal, Simbholi, Atrauli, Khurja and Debai were carrying 67MW, 55MW, 59MW, 27MW and 139MW respectively. बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 37 of 38 Preliminary report from 220kV NAPP(NP): Delayed clearance of fault (400ms) as observed in PMU and tripping incidents in generation complex area lead to sudden significant generation loss, which affect the reliability and security of the grid. Further, Nuclear plants get poisoned out if supply is not restored within 20 minutes and can be revived after 72 hours. Therefore, it is requested that the events may be analysed in detail and shortcomings in the operation and protection system/Auxiliary supply may be immediately resolved. A confirmation of the actions taken along with detailed report may please be submitted to NRLDC/ NRPC. NAPP may like to update the action taken in this regard. ***** बैठक ﴂकायग ूची:उ.क्षे.सव. .की प्रचालन मन्वय उप- समसत की 186वी पृष्ठ - 38 of 38 Follow up issues from previous OCC meetings All the concerned states had been requested in past OCC meetings to submit the details of the Sub-stations likely downstream network associated Status details of downstream networks 1 to be commissioned specially with POWERGRID mentioned in Annexure-A.I.I. by next two years. substations along with the action plan of their proposed / approved networks. Data upto following months, received from various states / UTs: ◎ CHANDIGARH Sep-2019 ◎ DELHI Jul-2021 Progress of Information regarding ◎ HARYANA Apr-2021 installing new installation of new capacitors ◎ HP Mar-2021 2 capacitors and and repair of defective ◎ J&K and LADAKH Not Available repair of defective capacitors is to be submitted to ◎ PUNJAB Mar-2021 capacitors NRPC Secretariat. ◎ RAJASTHAN Jul-2021 ◎ UP May-2021 ◎ UTTARAKHAND Jun-2021 All States/UTs are requested to furnish updated status on monthly basis. Data upto following months, received from various states / UTs: ◎ CHANDIGARH Not Available Report of mock exercise for ◎ DELHI Mar-2021 healthiness of UFRs carried out ◎ HARYANA Jun-2021 by utilities themselves on ◎ HP Jun-2021 Healthiness of quarterly basis is to be ◎ J&K and LADAKH Not Available 3 defence mechanism: submitted to NRPC Secretariat and ◎ PUNJAB Mar-2021 Self-certification NRLDC. All utilities were advised ◎ RAJASTHAN Jun-2021 to certify specifically, in the ◎ UP Jun-2021 report that “All the UFRs are ◎ UTTARAKHAND Mar-2021 checked and found functional”. ◎ BBMB Jun-2021 All States/UTs are requested to furnish updated status on monthly basis. Status of the information submission List of FGDs to be installed in (month) from states / utilities is as NR was finalized in the 36th TCC under: (special) meeting dt. 14.09.2017. ◎ HARYANA Feb-2021 All SLDCs were regularly ◎ PUNJAB May-2021 Status of FGD requested since 144th OCC meeting ◎ RAJASTHAN Jul-2021 installation vis-à- to take up with the concerned ◎ UP Jul-2021 4 vis installation generators where FGD was required ◎ NTPC May-2021 plan at identified to be installed. FGD status details are enclosed as TPS Further, progress of FGD Annexure-A.I.II. installation work on monthly All States/utilities are requested to basis is monitored in OCC furnish updated status of FGD meetings. installation progress on monthly basis. Reactive compensation at 220 kV/ 400 kV level at 15 substations 5 State / Substation Reactor Status Utility Anticipated commissioning: Dec’2021 i POWERGRID Kurukshetra 500 MVAr TCR (delay due to pending supplies by GE) PO awarded to M/s Kanohar Electricals Ltd. Drawings approved and under ii DTL Peeragarhi 1x50 MVAr at 220 kV stage inspection. GIS Bay is already available. Work expected to be completed by Dec.21 PO awarded to M/s Kanohar Electricals Ltd. Drawings approved and under iii DTL Harsh Vihar 2x50 MVAr at 220 kV stage inspection. GIS Bay is already available. Work expected to be completed by Dec.21 Bay work awarded to M/s. Ethos. Bay work is expected to be completed by 1x125 MVAr at 400 kV & iv DTL Mundka Dec.21. Reactor part tender is 1x25 MVAr at 220 kV dropped and at present same is under revision. Bay work awarded to M/s. Ethos. Bay work is expected to be completed by v DTL Bamnauli 2x25 MVAr at 220 kV Dec.21. Reactor part tender is dropped and at present same is under revision. Bay work awarded to M/s. Ethos. Bay work is expected to be completed by vi DTL Indraprastha 2x25 MVAr at 220 kV Dec.21. Reactor part tender is dropped and at present same is under revision. vii DTL Electric Lane 1x50 MVAr at 220 kV PR No 1100002374, Under Tendering Retendering to be done for 400kV 1x125 MVAr at 400 kV & viii PUNJAB Dhuri reactors. LOA placed for 220kV 1x25 MVAr at 220 kV reactors. ix PUNJAB Nakodar 1x25 MVAr at 220 kV Technical bids opened on 14.01.2021. Already submitted to PSDF. On hold x PTCUL Kashipur 1x125 MVAR at 400 kV due to policy decision LOA placed on dt. 4.1.2021. Agreement signed on dt. 8.02.2021. Case for 2nd xi RAJASTHAN Akal 1x25 MVAr installment would be forwarded to NLDC, POSOCO. The target date is Nov’2021. LOA placed on dt. 4.1.2021. Agreement signed on dt. 8.02.2021. Case for 2nd xii RAJASTHAN Bikaner 1x25 MVAr installment would be forwarded to NLDC, POSOCO. The target date is Nov’2021. LOA placed on dt. 4.1.2021. Agreement signed on dt. 8.02.2021. Case for 2nd xiii RAJASTHAN Suratgarh 1x25 MVAr installment would be forwarded to NLDC, POSOCO. The target date is Nov’2021. Agreement signed on dt. 22.06.2020. Barmer & Grant of Ist Installment received on xiv RAJASTHAN 13x25 MVAr others dt.19.02.21. Bidding document is under approval. Agreement signed on dt. 22.06.2020. Grant of Ist Installment received on xv RAJASTHAN Jodhpur 1x125 MVAr dt.19.02.21. Bidding document is under approval. Sl. Downstream Commissioning Planned 220 kV Revised Substation Remarks No. network bays status of ICTs / Bays system Target LILO of 220 kV Bishnha – Hiranagar 2 nos. bays Commissioning of ICT D/c line. Not Available Charged on 11.05.2021 400/220kV, utilized under 1st & 2nd - Mar’13 Original schedule - 1 3x315 MVA ISTS. 3rd - Oct’16 Nov'2019 Samba Balance 4 nos. to Commissioning of 220 kV D/c Samba be utilized Bays Mar’13 (PG) – Samba Bay charged on 17.05.2021; Not Available (JKPDD) approved in Line charging is remaining 1st NRSCT. Ckt-1 has been charged; Commissioning of ICT 220 kV New Wanpoh 400/220kV, Not Available Ckt-2 FTC is under process 6 Nos. of 220 kV Jul’14 -Mirbazar D/c line 2 2x315 MVA New at NRLDC end bays to be utilized Commissioning of Wanpoh 220 kV Alusteng - Bays Jul’14 Not Available Information not submitted New Wanpoh Line Shajahnapur- Jun'21 Updated in 179th OCC Commissioning of ICT Azimpur D/C line Shahjahanpur, 4 Nos. of 220 kV Commissioning of LILO of 220kV 3 2x315 MVA bays to be utilized Bays Shajahanpur - 400/220 kV Jul'21 Updated in 184th OCC Jun/Sep’14 Sitapur at Shajahanpur PG Commissioning of ICT 1st -Dec’13 Hamirpur 2nd - Mar’14 400/220 kV 2x 2 nos. bays 220 kV D/C Hamirpur- 3rd - Mar’19 315 MVA S/s utilized under Dehan line. 4 Commissioning of Jun'21 Updated in 180th OCC (Augmentation ISTS. Balance 6 Original schedule: Bays by 3x105 MVA nos to be utilized Dec' 2020 4 bays - Dec’13 ICT) 2 bays - Mar’14 2 bays - Mar’19 Work order was placed on dt. 13.04.2020 to M/s A to Z Ltd. Works start on dt. 4.12.2020. S/S-32/32, T/E- Sikar 2 Nos. of 220 kV Commissioned (date 31/32 (T/E at 27 no. location 5 400/220kV, Not available Jul'21 bays not available) is pending due to Rajasthan 1x 315 MVA S/s High Court stay), T/S- 2.09/8.122 km completed. Targeted to be completed by June’2021. 220kV Bhiwani (PG) - Execution Bhiwani 6 nos. of 220kV Commissioned (date Isherwal (HVPNL) 6 Aug'21 delayed due to 400/220kV S/s bays not available) D/c impact of COVID19. line RK Puram – PO for supply and ETC of Tughlakabad (UG Jul'22 D/C UG cable awarded. Cable) 220kv D/c line 400/220kV 10Nos. of 220kV Commissioned (date 7 Tughlakabad bays not available) GIS Masjid Mor – PO for supply and ETC of Tughlakabad 220kv Mar'22 D/C UG cable awarded. D/c line 220kV D/c line from 400/220kV Details for utilizing 6 Nos. of 220kV Commissioned in Kala Amb 400/220kV 8 Kala Amb GIS Dec'21 remaining 4 bays is not bays Jul'2017 S/s to 220/132kV (TBCB) available Kala Amb S/s FGD Status Updated status of FGD related data submission NTPC (16.06.2021) MEJA Stage-I PSPCL (17.06.2021) RIHAND STPS GGSSTP, Ropar SINGRAULI STPS GH TPS (LEH.MOH.) TANDA Stage-I RRVUNL (06.07.2021) TANDA Stage-II CHHABRA SCPP UNCHAHAR TPS CHHABRA TPP UPRVUNL (16.07.2021) KALISINDH TPS ANPARA TPS KOTA TPS HARDUAGANJ TPS SURATGARH SCTPS OBRA TPS SURATGARH TPS PARICHHA TPS Pending submissions Adani Power Ltd. Lanco Anpara Power Ltd. KAWAI TPS ANPARA C TPS APCPL NTPC INDIRA GANDHI STPP DADRI (NCTPP) GVK Power Ltd. Prayagraj Power Generation Company Ltd. GOINDWAL SAHIB PRAYAGRAJ TPP HGPCL Rosa Power Supply Company PANIPAT TPS ROSA TPP Ph-I RAJIV GANDHI TPS Talwandi Sabo Power Ltd. TALWANDI SABO TPP YAMUNA NAGAR TPS Lalitpur Power Gen. Company Ltd. L&T Power Development Ltd. LALITPUR TPS Nabha TPP (Rajpura TPP) Status Utility Project Unit-No. Unit-Capacity FGD-Status MAHATMA GANDHI China Light Power 1 660 TPS FGD Installed MAHATMA GANDHI China Light Power 2 660 TPS HGPCL PANIPAT TPS 6 210 HGPCL PANIPAT TPS 7 250 HGPCL PANIPAT TPS 8 250 HGPCL RAJIV GANDHI TPS 1 600 Updated status to be submitted HGPCL RAJIV GANDHI TPS 2 600 HGPCL YAMUNA NAGAR TPS 1 300 HGPCL YAMUNA NAGAR TPS 2 300 APCPL INDIRA GANDHI STPP 1 500 Bid awarded on 30 Jan 2018. Updated APCPL INDIRA GANDHI STPP 2 500 status to be submitted by APCPL APCPL INDIRA GANDHI STPP 3 500 Status Utility Project Unit-No. Capacity FGD-Status GOINDWAL GVK Power Ltd. 1 270 SAHIB EOI was invited vide newspaper advrt. On 18.06.2018 GOINDWAL GVK Power Ltd. 2 270 SAHIB Talwandi Sabo TALWANDI SABO 1 660 Power Ltd. TPP Talwandi Sabo TALWANDI SABO 2 660 Feasibility Study Carried Out. PPA issues pending with regulator Power Ltd. TPP Talwandi Sabo TALWANDI SABO 3 660 Power Ltd. TPP L&T Power Nabha TPP PSERC disallowed additional capital cost pass through under Development Ltd 1 700 (Rajpura TPP) “Change in Law” provisions of PPA on the ground that (Nabha) Environment Clearance required space provision for FGD. Tendering process got stalled due to regulatory hurdles as Banks L&T Power put a condition of Regulatory clarity and additional capital cost Nabha TPP Development Ltd 2 700 pass through under PPA provisions. (Rajpura TPP) (Nabha) NPL approached the Appellate Tribunal. Status Utility Project Unit-No. Unit-Capacity FGD-Status GH TPS PSPCL 1 210 (LEH.MOH.) GH TPS As per decision of WTDs of PSPCL in 242nd meeting held on 26-08- PSPCL 2 210 (LEH.MOH.) 2020, the bidding process for installation of wet lime based FGD system has been closed due to very low PLF of GHTP units and for floating fresh tender for installation of DSI based FGD system at GH TPS GHTP, the matter is being taken up with NTPC for feasibility study PSPCL 3 250 (LEH.MOH.) and preparation of techno-commercial tender specifications GH TPS PSPCL 4 250 (LEH.MOH.) Status Utility Project Unit-No. Unit-Capacity FGD-Status PSPCL GGSSTP, Ropar 3 210 Tender enquiry has been dropped & PSPCL GGSSTP, Ropar 4 210 fresh enquiry to be floated as per guidelines after approval of PSPCL GGSSTP, Ropar 5 210 आ配मनिर्भर comp. Auth. PSPCL GGSSTP, Ropar 6 210 Status Utility Project Unit-No. Unit-Capacity FGD-Status RRVUNL KOTA TPS 5 210 NIT for Partial Wet FGD installation has been floated on 1/6/21 RRVUNL KOTA TPS 6 195 For De-NOx installations, technology (SCR/SNCR/Combustion Optimization) to be adopted shall be finalized after verification of Pilot Plant RRVUNL KOTA TPS 7 195 Studies by NTPC and CEA. Approval of State Govt. for Additional Capital Cost & Additional Equity has been accorded. RRVUNL SURATGARH TPS 1 250 Preparation of Tech. Specifications for installation of RRVUNL SURATGARH TPS 2 250 partial Wet FGD with common absorber at SSTPS Suratgarh in line with CEA advice dt. 07.02.2020 is RRVUNL SURATGARH TPS 3 250 under process. For De-NOx installations, technology (SCR/SNCR/Combustion Optimization) to be adopted RRVUNL SURATGARH TPS 4 250 shall be finalized after verification of Pilot Plant Studies by NTPC and CEA. RRVUNL SURATGARH TPS 5 250 Approval of State Govt. for Additional Capital Cost & Additional Equity has been accorded. RRVUNL SURATGARH TPS 6 250 Status Utility Project Unit-No. Unit-Capacity FGD-Status Revised NIT for Wet FGD installation floated on RRVUNL SURATGARH SCTPS 7 660 25.03.2021. For De-NOx installations, technology (SCR/SNCR/Combustion Optimization) to be adopted shall be finalized after verification of Pilot Plant RRVUNL SURATGARH SCTPS 8 660 Studies by NTPC and CEA. Approval of State Govt. for Additional Capital Cost & Additional Equity has been accorded. RRVUNL CHHABRA TPP 1 250 RRVUNL CHHABRA TPP 2 250 RRVUNL CHHABRA TPP 3 250 For De-NOx installations, technology RRVUNL CHHABRA TPP 4 250 (SCR/SNCR/Combustion Optimization) to be adopted shall be finalized after verification of Pilot Plant RRVUNL CHHABRA SCPP 5 660 Studies by NTPC and CEA. Approval of State Govt. for Additional Capital Cost & RRVUNL CHHABRA SCPP 6 660 Additional Equity has been accorded. RRVUNL KALISINDH TPS 1 600 RRVUNL KALISINDH TPS 2 600 Status Utility Project Unit-No. Unit-Capacity FGD-Status Adani Power Ltd. KAWAI TPS 1 660 Updated status to be submitted Adani Power Ltd. KAWAI TPS 2 660 Lalitpur Power Gen. LALITPUR TPS 1 660 Company Ltd. Petition was filed with UPERC on 16.11.2017 for approval capital cost for installation of FGD and other associated systems. UPERC directed to approach CEA to decide specific optimum technology, Lalitpur Power Gen. LALITPUR TPS 2 660 associated cost and major issues to be faced for installation of Company Ltd. different system. CEA suggested technology and associated cost in Feb, 2019. Again petition filed in UPERC dt 21.05.2019 for in- Lalitpur Power Gen. principal approval of capital cost. Updated status to be submitted. LALITPUR TPS 3 660 Company Ltd. CEA informed LANPL to submit the Feasibility report prepared by external consultant with options available in the market and the Lanco Anpara Power Ltd. ANPARA C TPS 1 600 technology selected along with the cost. CEA issued a letter to submit a detailed feasibility report consisting of details / contents. To meet the above, LANPL appointed M/s/ Black & Veatch as consultant for Air Quality and control system (AQCS) for preparing the Feasibility report. With the present technologies available for reducing the emissions, Wet Lime Stone FGD System for SO2 Lanco Anpara Power Ltd. ANPARA C TPS 2 600 control is recommended by Black & Veatch. As soon as the Feasibility report is final, LANPL will submit the same to CEA for vetting and their approval. Status Utility Project Unit-No. Unit-Capacity FGD-Status NTPC DADRI (NCTPP) 1 210 NTPC DADRI (NCTPP) 2 210 DSI system is in operation NTPC DADRI (NCTPP) 3 210 NTPC DADRI (NCTPP) 4 210 NTPC DADRI (NCTPP) 5 490 Updated status of FGD installation for NTPC DADRI (NCTPP) 6 490 Dadri Unit# 5 & Unit#6 to be submitted NTPC RIHAND STPS 1 500 Updated plan not submitted NTPC RIHAND STPS 2 500 NTPC RIHAND STPS 3 500 NTPC RIHAND STPS 4 500 Contract awarded to M/s MHPS on 18-09- NTPC RIHAND STPS 5 500 18 NTPC RIHAND STPS 6 500 Status Utility Project Unit-No. Unit-Capacity FGD-Status NTPC SINGRAULI STPS 1 200 NTPC SINGRAULI STPS 2 200 NTPC SINGRAULI STPS 3 200 NTPC SINGRAULI STPS 4 200 NTPC SINGRAULI STPS 5 200 Contract awarded to M/s PES on 18-02-20 NTPC SINGRAULI STPS 6 500 NTPC SINGRAULI STPS 7 500 NTPC UNCHAHAR TPS 1 210 NTPC UNCHAHAR TPS 2 210 NTPC UNCHAHAR TPS 3 210 Contract awarded to M/s GE on 18-02-20 NTPC UNCHAHAR TPS 4 210 NTPC UNCHAHAR TPS 5 210 NTPC UNCHAHAR TPS 6 500 Contract awarded to M/s GE on 16-10-18 Status Utility Project Unit-No. Unit-Capacity FGD-Status NTPC MEJA Stage-I 1 660 Contract awarded to M/s GE on 20-09-18 NTPC MEJA Stage-I 2 660 NTPC TANDA Stage-I 1 110 Work completed NTPC TANDA Stage-I 2 110 NTPC TANDA Stage-II 3 660 Contract awarded to M/s GE on 18-09-18 NTPC TANDA Stage-II 4 660 Status Utility Project Unit-No. Unit-Capacity FGD-Status Prayagraj Power Generation Company PRAYAGRAJ TPP 1 660 Ltd. Feasibility Report cleared by CEA, Tariff Prayagraj Power petition being filed to state Regulator Generation Company PRAYAGRAJ TPP 2 660 (UPERC) and Tender Specifications under Ltd. preparation by consultants M/s TCE. Prayagraj Power Generation Company PRAYAGRAJ TPP 3 660 Ltd. Rosa Power Supply ROSA TPP Ph-I 1 300 Company Rosa Power Supply ROSA TPP Ph-I 2 300 Pending in UPERC for In-principle Company approval of capital cost for installation of Rosa Power Supply ROSA TPP Ph-I 3 300 FGD Company Rosa Power Supply ROSA TPP Ph-I 4 300 Company Status Utility Project Unit-No. Unit-Capacity FGD-Status UPRVUNL ANPARA TPS 1 210 UPRVUNL ANPARA TPS 2 210 Tender re-floated on 07.06.2021. UPRVUNL ANPARA TPS 3 210 UPRVUNL ANPARA TPS 4 500 Case put-up before CTC for tender cancellation and Re-Tendering to be UPRVUNL ANPARA TPS 5 500 done. UPRVUNL ANPARA TPS 6 500 27% work completed. Contract awarded UPRVUNL ANPARA TPS 7 500 on 04-07-19 UPRVUNL HARDUAGANJ TPS 8 250 Tender Cancelled and Re-Tendering to be UPRVUNL HARDUAGANJ TPS 9 250 done. Status Utility Project Unit-No. Unit-Capacity FGD-Status UPRVUNL OBRA TPS 9 200 UPRVUNL OBRA TPS 10 200 UPRVUNL OBRA TPS 11 200 Tender has been invited on 31.05.2021 UPRVUNL OBRA TPS 12 200 UPRVUNL OBRA TPS 13 200 UPRVUNL PARICHHA TPS 3 210 EOI has been invited on 29.05.2021 UPRVUNL PARICHHA TPS 4 210 UPRVUNL PARICHHA TPS 5 250 Re-tendering to be done. UPRVUNL PARICHHA TPS 6 250 Target Dates for FGD Commissioning INDIRA GANDHI STPP U#3 ,GOINDWAL SAHIB U#2 ,DADRI (NCTPP) U#6 ,PRAYAGRAJ TPP 29 February 2020 U#3 INDIRA GANDHI STPP U#2 ,GOINDWAL SAHIB U#1 ,DADRI (NCTPP) U#5 ,PRAYAGRAJ TPP 30 April 2020 U#1 30 June 2020 KAWAI TPS U#2 ,DADRI (NCTPP) U#4 ,PRAYAGRAJ TPP U#2 31 August 2020 KAWAI TPS U#1 ,DADRI (NCTPP) U#3 31 October 2020 INDIRA GANDHI STPP U#1 ,TALWANDI SABO TPP U#3 ,DADRI (NCTPP) U#2 31 December 2020 PANIPAT TPS U#8 ,TALWANDI SABO TPP U#2 ,LALITPUR TPS U#1 ,DADRI (NCTPP) U#1 PANIPAT TPS U#7 ,TALWANDI SABO TPP U#1 ,Nabha TPP (Rajpura TPP) U#2 ,LALITPUR 28 February 2021 TPS U#2 30 April 2021 PANIPAT TPS U#6 ,Nabha TPP (Rajpura TPP) U#1 ,ANPARA TPS U#7 30 June 2021 ANPARA TPS U#6 31 October 2021 YAMUNA NAGAR TPS U#2 ,LALITPUR TPS U#3 ,ROSA TPP Ph-I U#3 ,ROSA TPP Ph-I U#4 YAMUNA NAGAR TPS U#1 ,RIHAND STPS U#2 ,ROSA TPP Ph-I U#1 ,ROSA TPP Ph-I U#2 31 December 2021 ,HARDUAGANJ TPS U#8 ,HARDUAGANJ TPS U#9 ,PARICHHA TPS U#6 RAJIV GANDHI TPS U#2 ,GH TPS (LEH.MOH.) U#3 ,GH TPS (LEH.MOH.) U#4 ,RIHAND 28 February 2022 STPS U#1 ,ANPARA TPS U#5 ,PARICHHA TPS U#5 GGSSTP, Ropar U#3 ,GGSSTP, Ropar U#4 ,GGSSTP, Ropar U#5 ,GGSSTP, Ropar U#6 ,MEJA 31 March 2022 Stage-I U#1 ,MEJA Stage-I U#2 RAJIV GANDHI TPS U#1 ,GH TPS (LEH.MOH.) U#1 ,GH TPS (LEH.MOH.) U#2 ,ANPARA TPS 30 April 2022 U#4 ,OBRA TPS U#13 ,PARICHHA TPS U#3 ,PARICHHA TPS U#4 30 June 2022 ANPARA C TPS U#2 ,ANPARA TPS U#3 ,OBRA TPS U#12 ANPARA C TPS U#1 ,SINGRAULI STPS U#1 ,SINGRAULI STPS U#2 ,SINGRAULI STPS U#3 31 August 2022 ,SINGRAULI STPS U#4 ,SINGRAULI STPS U#5 ,SINGRAULI STPS U#6 ,SINGRAULI STPS U#7 ,ANPARA TPS U#2 ,OBRA TPS U#9 31 October 2022 KOTA TPS U#7 ,ANPARA TPS U#1 ,OBRA TPS U#10 31 December 2022 KOTA TPS U#5 ,KOTA TPS U#6 ,OBRA TPS U#11 ,TANDA Stage-II U#3 ,TANDA Stage-II U#4 31 March 2023 UNCHAHAR TPS U#6 30 June 2023 RIHAND STPS U#5 ,RIHAND STPS U#6 UNCHAHAR TPS U#1 ,UNCHAHAR TPS U#2 ,UNCHAHAR TPS U#3 ,UNCHAHAR TPS U#4 30 September 2023 ,UNCHAHAR TPS U#5 31 December 2023 RIHAND STPS U#3 ,RIHAND STPS U#4 SURATGARH TPS U#1 ,SURATGARH TPS U#2 ,SURATGARH TPS U#3 ,SURATGARH TPS U#4 ,SURATGARH TPS U#5 ,SURATGARH TPS U#6 ,SURATGARH SCTPS U#7 ,SURATGARH SCTPS 31 December 2024 U#8 ,CHHABRA TPP U#1 ,CHHABRA TPP U#2 ,CHHABRA TPP U#3 ,CHHABRA TPP U#4 ,CHHABRA SCPP U#5 ,CHHABRA SCPP U#6 ,KALISINDH TPS U#1 ,KALISINDH TPS U#2 NA TANDA Stage-I U#1 ,TANDA Stage-I U#2 Target Dates for FGD Commissioning (Utility-wise) KAWAI TPS U#1 (Target: 31-08-2020), KAWAI TPS U#2 (Target: 30-06- Adani Power Ltd. 2020) INDIRA GANDHI STPP U#1 (Target: 31-10-2020), INDIRA GANDHI STPP APCPL U#2 (Target: 30-04-2020), INDIRA GANDHI STPP U#3 (Target: 29-02- 2020) China Light MAHATMA GANDHI TPS U#1 (Target: NA), MAHATMA GANDHI TPS U#2 Power (Target: 31-01-2019) GOINDWAL SAHIB U#1 (Target: 30-04-2020), GOINDWAL SAHIB U#2 GVK Power Ltd. (Target: 29-02-2020) PANIPAT TPS U#6 (Target: 30-04-2021), PANIPAT TPS U#7 (Target: 28-02- 2021), PANIPAT TPS U#8 (Target: 31-12-2020), RAJIV GANDHI TPS U#1 HGPCL (Target: 30-04-2022), RAJIV GANDHI TPS U#2 (Target: 28-02-2022), YAMUNA NAGAR TPS U#1 (Target: 31-12-2021), YAMUNA NAGAR TPS U#2 (Target: 31-10-2021) DADRI (NCTPP) U#1 (Target: 31-12-2020), DADRI (NCTPP) U#2 (Target: 31-10- 2020), DADRI (NCTPP) U#3 (Target: 31-08-2020), DADRI (NCTPP) U#4 (Target: 30- 06-2020), DADRI (NCTPP) U#5 (Target: 30-04-2020), DADRI (NCTPP) U#6 (Target: 29-02-2020), RIHAND STPS U#1 (Target: 28-02-2022), RIHAND STPS U#2 (Target: 31-12-2021), RIHAND STPS U#3 (Target: 31-12-2023), RIHAND STPS U#4 (Target: 31-12-2023), RIHAND STPS U#5 (Target: 30-06-2023), RIHAND STPS U#6 (Target: 30-06-2023), SINGRAULI STPS U#1 (Target: 31-08-2022), SINGRAULI STPS U#2 (Target: 31-08-2022), SINGRAULI STPS U#3 (Target: 31-08-2022), SINGRAULI STPS NTPC U#4 (Target: 31-08-2022), SINGRAULI STPS U#5 (Target: 31-08-2022), SINGRAULI STPS U#6 (Target: 31-08-2022), SINGRAULI STPS U#7 (Target: 31-08-2022), UNCHAHAR TPS U#1 (Target: 30-09-2023), UNCHAHAR TPS U#2 (Target: 30-09- 2023), UNCHAHAR TPS U#3 (Target: 30-09-2023), UNCHAHAR TPS U#4 (Target: 30-09-2023), UNCHAHAR TPS U#5 (Target: 30-09-2023), UNCHAHAR TPS U#6 (Target: 31-03-2023), MEJA Stage-I U#1 (Target: 31-03-2022), MEJA Stage-I U#2 (Target: 31-03-2022), TANDA Stage-I U#1 (Target: ), TANDA Stage-I U#2 (Target: ), TANDA Stage-II U#3 (Target: 31-12-2022), TANDA Stage-II U#4 (Target: 31-12- 2022) L&T Power Nabha TPP (Rajpura TPP) U#1 (Target: 30-04-2021), Nabha TPP (Rajpura TPP) U#2 (Target: 28- Development Ltd 02-2021) (Nabha) Lalitpur Power LALITPUR TPS U#1 (Target: 31-12-2020), LALITPUR TPS U#2 (Target: 28-02-2021), LALITPUR Gen. Company Ltd. TPS U#3 (Target: 31-10-2021) Lanco Anpara ANPARA C TPS U#1 (Target: 31-08-2022), ANPARA C TPS U#2 (Target: 30-06-2022) Power Ltd. Prayagraj Power PRAYAGRAJ TPP U#1 (Target: 30-04-2020), PRAYAGRAJ TPP U#2 (Target: 30-06-2020), Generation PRAYAGRAJ TPP U#3 (Target: 29-02-2020) Company Ltd. GH TPS (LEH.MOH.) U#1 (Target: 30-04-2022), GH TPS (LEH.MOH.) U#2 (Target: 30-04-2022), GH TPS (LEH.MOH.) U#3 (Target: 28-02-2022), GH TPS (LEH.MOH.) U#4 (Target: 28-02-2022), PSPCL GGSSTP, Ropar U#3 (Target: 31-03-2022), GGSSTP, Ropar U#4 (Target: 31-03-2022), GGSSTP, Ropar U#5 (Target: 31-03-2022), GGSSTP, Ropar U#6 (Target: 31-03-2022) Rosa Power Supply ROSA TPP Ph-I U#1 (Target: 31-12-2021), ROSA TPP Ph-I U#2 (Target: 31-12-2021), ROSA TPP Ph-I Company U#3 (Target: 31-10-2021), ROSA TPP Ph-I U#4 (Target: 31-10-2021) KOTA TPS U#5 (Target: 31-12-2022), KOTA TPS U#6 (Target: 31-12-2022), KOTA TPS U#7 (Target: 31- 10-2022), SURATGARH TPS U#1 (Target: 31-12-2024), SURATGARH TPS U#2 (Target: 31-12-2024), SURATGARH TPS U#3 (Target: 31-12-2024), SURATGARH TPS U#4 (Target: 31-12-2024), SURATGARH TPS U#5 (Target: 31-12-2024), SURATGARH TPS U#6 (Target: 31-12-2024), RRVUNL SURATGARH SCTPS U#7 (Target: 31-12-2024), SURATGARH SCTPS U#8 (Target: 31-12-2024), CHHABRA TPP U#1 (Target: 31-12-2024), CHHABRA TPP U#2 (Target: 31-12-2024), CHHABRA TPP U#3 (Target: 31-12-2024), CHHABRA TPP U#4 (Target: 31-12-2024), CHHABRA SCPP U#5 (Target: 31-12-2024), CHHABRA SCPP U#6 (Target: 31-12-2024), KALISINDH TPS U#1 (Target: 31-12-2024), KALISINDH TPS U#2 (Target: 31-12-2024) Talwandi Sabo TALWANDI SABO TPP U#1 (Target: 28-02-2021), TALWANDI SABO TPP U#2 (Target: 31-12-2020), Power Ltd. TALWANDI SABO TPP U#3 (Target: 31-10-2020) ANPARA TPS U#1 (Target: 31-10-2022), ANPARA TPS U#2 (Target: 31-08-2022), ANPARA TPS U#3 (Target: 30-06-2022), ANPARA TPS U#4 (Target: 30-04-2022), ANPARA TPS U#5 (Target: 28-02- 2022), ANPARA TPS U#6 (Target: 30-06-2021), ANPARA TPS U#7 (Target: 30-04-2021), HARDUAGANJ TPS U#8 (Target: 31-12-2021), HARDUAGANJ TPS U#9 (Target: 31-12-2021), OBRA UPRVUNL TPS U#9 (Target: 31-08-2022), OBRA TPS U#10 (Target: 31-10-2022), OBRA TPS U#11 (Target: 31- 12-2022), OBRA TPS U#12 (Target: 30-06-2022), OBRA TPS U#13 (Target: 30-04-2022), PARICHHA TPS U#3 (Target: 30-04-2022), PARICHHA TPS U#4 (Target: 30-04-2022), PARICHHA TPS U#5 (Target: 28-02-2022), PARICHHA TPS U#6 (Target: 31-12-2021) भारत सरकार /Government of India विधुत मंत्रालय/Ministry of Power कᴂद्रिय विधुत प्राधधकरण/Central Electricity Authority रा.वि.स. प्रभाग/National Power Committee Division 1st Floor, Wing-5, West Block-II, RK Puram, New Delhi-66 F. No. CEA-GO-15-14/4/2021-NPC Division-Part(1) Dated: 06.08.2021 To (As per distribution list) विषय: द्रि쥍ली, मुԂबई, चेꅍनई, कोलकाता, बԂगलोर और असम की 饍िीपीय योजनाओԂ की समीक्षा के ललए बैठक के सԂबԂध मᴂ l Subject : Meeting to review the Islanding Schemes of Delhi, Mumbai, Chennai, Bangalore, Kolkata and Assam-Reg. The Minutes of the meeting held on 29th July 2021 at 03:00 PM through video conference to review the Islanding Schemes of Delhi, Mumbai, Chennai, Bangalore, Kolkata and Assam with the Member Secretaries of all RPCs and the concern utilities are attached herewith for your kind information and necessary action, please. Encl: As above. -Sd- (ऋषिका शरण /Rishika Sharan) मु奍य अभियꅍता (रा.षि.स.)/Chief Engineer (NPC) Distribution List: 1. Shri Naresh Bhandari, Member Secretary, NRPC, 18-A, Shaheed Jeet Singh Marg, Katwaria Sarai, New Delhi-110016.[ Email: [email protected]] 2. Shri Satyanarayan S., Member Secretary, WRPC, Plot No. F-3, MIDC Area, Marol, Opp. SEEPZ, Central Road, Andheri (East), Mumbai-400093. [Email: ms- [email protected]] 3. Shri A.Balan, Member Secretary, SRPC, No.29, Race Course Cross Road, Bengaluru- 560009. [Email: [email protected]] 4. Shri N. S. Mondal, Member Secretary, ERPC, 14, Golf Club Road, ERPC Building, Tollygunje,Kolkata-700 033.[ Email: [email protected]] 5. Shri A. K. Thakur, Member Secretary, NERPC, NERPC Complex, Dong Parmaw, Lapalang, Shillong-793006. [Email: [email protected] ] 6. Shri Rajesh Lakhoni, IAS, Chairman, TANTRANSCO, 144, Anna Salai, Chennai – 600002.(Email: [email protected] ) Tel: 044-28521300 7. Shri Sh. S. Shanmugam, Managing Director, TANTRANSCO, 144, Anna Salai, Chennai – 600002. (Email: [email protected]) Tel: 044-28521057 8. Shri Rajesh Lakhoni, IAS, CMD, TANGEDCO, 6th Floor, TANTRANSCO Building, 144, Anna Salai, Chennai – 600002.(Email: [email protected] ) Tel: 044- 28521300 9. Director/Generation, TANGEDCO, 5th Floor, TANTRANSCO Building, 144, Anna Salai, Chennai – 600002. (Email: [email protected] ) Tel: 044-28521915 10. Shri Basavaraj Goswami, CEO, NTECL, Vallur Thermal Power Project, Vellivoyal Chavadi P O, Ponneri Taluk, Thiruvallur District, Chennai-600103. (Email: [email protected]) Mob: 9650992094 11. Shri M. Balarama Murthy, Station Director, Madras Atomic Power Station, Post Office: Kalpakkam, Kancheepuram-603102. (Email: [email protected]) Mob: 9442644103 12. Shri S Ravi, Executive Director, SR-IIm Powergrid Corporation of India, Southern Region- II, Doddaballapur Road, Singanaykanahalli, Yelahanka, Bangalore-560064, Near RTO. (Email: [email protected]) Mob: 9440908902 13. Shri Rabi Chowdhury, Managing Director (Generations), ERPC member, CESC Limited, CESC House, Chowringhee Square, Kolkata-700 001 ( Email: [email protected] ) Mob: 9831054654 14. Mr. Sandip Pal, Vice President ( System Operations), TCC Member, CESC Limited, CESC House, Chowringhee Square, Kolkata-700 001 (Email: [email protected] ) Mob: 9831054651 15. Dr Satya Gopal, IAS, Additional Chief Secretary (Power) Chairman & Managing, DTL, Shakti Sadan, Kotla Marg, New Delhi-110002. (Email: [email protected], [email protected]) Tel: 011-23392047 16. Shri Amal Sinha, CEO, Delhi. (Email: [email protected]) Tel: 011-39999838 17. Shri Prem R Kumar, CEO, BSES Yamuna Power Limited, Shakti Kiran Building, Karkarddoma, New Delhi-110032. (Email: [email protected]) 18. Shri Sanjay Kumar Banga, CEO,Delhi. (Email: [email protected]) Mob: 7042244177 19. Sri Paban Bora, CGM, SLDC, O/o the CGM, SLDC, AEGCL, Kahilipra, Guwahati- 19. (Email: [email protected]) Mob: 8638174429 20. Shri Gunajit Bhuyan, CGM(O&M), LAR, O/o the MD, AEGCL, Bijulee Bhawan, Paltan Bazar, Guwahati-1. (Email: cgmom,[email protected]) Mob: 9854015601 21. Shri Madan Mohan Brahma, CGM (T&C and Communciation) O/o the MD, AEGCL, Bijulee Bhawan, Paltan Bazar, Guwahati-1. (Email: [email protected]) Mob: 9435326113 22. Shri Nabarun Roy, Executive Director, NERLDC, Shillong. (Email: [email protected]) Mob: 9869080265 23. Shri S C Dey, Sr. General Manager, NERLDC, Shillong. (Email:[email protected]) Mob: 9436335369 24. Shri D.P. Patra, GM (Plant), NTPC, Bangaigoan. (Email: [email protected]) Mob: 8275045446 25. Shri U.Kataki, CGM (AM), NERTS, Shillong. (Email: [email protected]) Mob: 9435505418 26. Shri D.M. Devasthale, Adani Power (Email: [email protected]) Mob: 9324180932 27. Shri P Devanand, Tata Power (Email:[email protected]) Mob: 9871800506 28. Shri P.S.Sharma, S.E., MSETCL, (Email: [email protected]) Mob: 9769213865 29. Shri Vasant Pande, SLDC, SLDC Maharashtra (Email: [email protected]) Mob: 9137868425 30. Shri Mohan R. Waingankar, Adani Power, (Email: [email protected]) Mob: 9324216664 31. Shri Rajurkar, MSETCL (Email: [email protected]) 32. Shri N.S. Teltambde, MSETCL, 135 PCM, MSETCL (Email: [email protected]) 33. Shri P.S.Sharma, MSETCL, PCM, MSETCL (Email: seprotection@gmail,com) Mob: 9769213865 34. Sh. Girish Jawale, Tata Power (Email: [email protected]) Mob: 9223311419 35. Shri B. Lyngkhoi, Director/SE, NERPC, NERPC Complex, Dong Parmaw, Lapalang, Shillong-793006. (Email: [email protected]) Mob: 9436163419 36. Chairperson, Karnataka Power Transmission Corporation Limited, Corporate office, Kaveri Bhavan, K.G. Road, Bengaluru-560009. [Email: [email protected], [email protected]]. Tel: 080-22128327 37. Dr. N. Manjula, MD, Karnataka Power Transmission Corporation Limited, Corporate office, Kaveri Bhavan, K.G.Road, Bengaluru-560009. [Email:[email protected]], Tel: 080-22212014 38. Sh. V. Pannuraj, MD, Karnataka Power Corporation Limited, No. 82, Shakti Bhawan, Race Course Road, Bengaluru-560001. [Email:[email protected]] , Tel: 080- 22255606 39. Sh. Anoop Kumar, Executive Director (SR-I), PGCIL, 6-6-8/32, 395B, Old Praga Tools Premises, Kavadiguda Road, Secunderabad, Telangana – 5500080.[Email: [email protected]] , Tel: 040-27546636 40. Sh. R K Chauhan, Executive Director, HVDC-Engg, Saudamini, Plot No. 2, Sector-29, Gurugram-122001. Tel: 0124-2571820 41. Sh. S Ravi , Executive Director (SR-II), PGCIL, near RTO Driving Test Track, Singanayakanahalli, Yolahanka Hobli, Bangalore-560064, Karnataka. [Email: [email protected]] Mob: 9440908902 42. Sh. Rajendra Kumar Gupta, Site Director, NPCIL, KGS, Kalga Atomic Power Station Rd., Post office: Kalga, Uttara Kannada, Karwar, Karnataka-581400. [Email: [email protected]] Mob: 08382264016, 9423081697 43. Sh. S.Y.Sarwate, ACE (Transmission), NPCIL, Mumbai-NPCIL, HQ, Nabhidya Urja Bhavan, Anushaktinagar, Mumbai – 400094. [Email: [email protected]] Mob: 9869441211 44. Sh. Uday Trivedi, Vice President-ENDORSE Protection & Metering, Adani Power Ltd. Adani House, Shantigram, Near Vaishnodevi Circle, SG Highway, Ahmedabad- 382421. [Email: [email protected]] Mob: 9099055054 ***** Minutes of the Meeting to review the Islanding Schemes of Delhi, Mumbai, Chennai, Bangalore, Kolkata and Assam held on 29th July 2021 through video conference Member (GO&D), CEA reviewed the Islanding Schemes (IS) of Delhi, Mumbai, Chennai, Bangalore, Kolkata & Assam and Bangalore(New IS) in a meeting with the Member Secretaries of all RPCs and the concern utilities held on 29th July 2021 at 03:00 PM through video conference. List of participants at Annexure-I. 1. Member (GO&D) ,CEA welcomed all the Member Secretaries of RPCs & concerned utilities. He requested Chief Engineer, NPC to take up the Agenda of the meeting. 2. CE, NPC presented a brief presentation on the background of the Islanding Scheme. She informed about the decisions taken in the Review meeting of Islanding Scheme chaired by Honorable Minister (Power& NRE) on 28.12.2020 and Secretary (Power) meeting held on 31.03.2021 and 16.04.2021. She also informed about the actions taken on the decisions in these meetings. The presentation is at Annexure-II. Then the agenda of the meeting was taken up. 3. Review of Mumbai Islanding Scheme (IS): 3.1 MS (WRPC) informed that at present, Mumbai Islanding schemes covers Mumbai city with super critical load of 700 MW (includes defence load of 300 MW) and critical load of 500 MW. The embedded / inland generation of Mumbai is around 1877 MW and Daily average load fed is around 3000 MW. 3.2 The following constraints were observed in the Mumbai IS: (i) Scheduling is being done by DISCOMs in accordance with the Merit Order Dispatch (MOD). In MOD, some embedded/inland generation may not get Schedule and due to this there is load generation imbalance during islanding. (ii) Maharashtra SLDC informed that about 1032MW of embedded generation is available and when some units are under zero schedule and one or two 400kV line tripped then it becomes difficult to feed the loads of the Mumbai IS. 3.3 MS, WRPC informed that after the incidents of blackout in Mumbai, following steps were taken up for successful operations of Mumbai Islanding: (i) MS WRPC informed that the scheme was reviewed on 04/04/2021. During the discussion in the review meeting, representatives of APL, TPC, MSLDC / MSETC informed that after 12th October incident, except 700 MW super critical load of Mumbai all other loads are wired with UFR by APL and TPC. (ii) It was also informed that the under frequency load setting was changed from 48.0 Hz to 48.4 Hz so that more cushion would be available for system to survive. To handle the tripping of unit 7 of TATA Hydro, more loads are to be shed. Additional load shedding (of house load) at 47 Hz to handle unit 7 trip has been implemented. (iii) System Studies of Mumbai IS is being carried out by IIT Bombay and the scheme would be reviewed again after the outcome of the study. Based on above discussions following decisions were taken: 3.4 Member (GO&D) opined that after implementing above measures, it appears that the chance of successful operations of Mumbai Islanding have increased. However, he advised that the Islanding Schemes could not be compromised due to MOD and expensive generation. The super critical Load and critical loads have to be fed during the Islanding. To ensure this, the necessary steps may have to be taken up by the concerned utilities. 4. Review of Delhi Islanding Scheme (IS): 4.1 Delhi IS covers the city of Delhi in which the super critical and critical load includes VVIP load of Central Delhi, Hospitals, MES load, DMRC, Railway load. The anticipated generation available is around 2532 MW and load to be fed during Islanding is around 2519 MW (includes 30 MW of MES load). It was observed that the difference between the anticipated load and anticipated generation was very less and hence the survival of Delhi IS was difficult. 4.2 MS, NRPC informed that the additional critical load relief of 500MW has been identified by DTL and hence the load to be fed during Islanding scheme has been reduced to 2019 MW. He further informed that the following issues were identified: (i) Segregation of critical loads at lower voltage level i.e., 11kV level so that quantum of Island load could be reduced. (ii) Scheduling of all generators participating in Delhi Island. (iii) Real time monitoring of participating generators and feeders catering the island load. 4.3 MS, NPRC informed that the following measures have been taken to fill above gaps: (i) Delhi’s DISCOMs (TPDDL, BRPL & BYPL) have identified their critical loads of 1032MW at lower voltage level (against their existing critical load of 2000MW – identified at 11KV & above). Additional relays would be required to reduce the island load. Commissioning of additional relays can commence after regulatory approval and the implementation can take 18 months after the approval. (ii) Delhi SLDC have been asked to approach DERC for getting must run status of Dadri-II and APCPL Jhajjar so that availability of Generation in Delhi from the identified Generating stations is more than total island load. (iii)Delhi SLDC/NRLDC have been requested to setup separate display of Islanding schemes on SCADA for real time monitoring of participating generators & critical loads by 31st July 2021. 4.4 MS, NRPC informed that TPDDL & BRPL had submitted their revised scheme to DERC and BYPL had yet to submit the scheme. 4.5 The representative of SLDC, Delhi stated that at the time of formation of Island, the system at 220 kV may experience high voltages & trip due to less load conditions. MS, NRPC informed that DERC had referred the study of sustainability of the Islanding scheme to SLDC, Delhi with 1032 MW load. Based on above discussions following decisions were taken: 4.6 Member (GO&D) directed BYPL to submit their scheme to DERC as soon as possible. Member (GO&D) advised Delhi SLDC to seek assistance for system study of the scheme from CEA/CTU, if required. 4.7 Member (GO&D) advised MS, NRPC to expedite the implementation of Delhi IS with 1032 MW island load. He also requested SLDC, Delhi to take up the matter urgently with DERC for getting must run status of Dadri-II and APCPL Jhajjar for a conclusive approach. Member (GO&D) opined that the present scheme of Delhi Islanding have operational constraints and shall again be reviewed within 14 days. 5. Review of Chennai Islanding Scheme (IS): 5.1 Chennai IS covers the city of Chennai and other towns like Ambattur, Avadi, etc. The anticipated generation available is around 2512 MW and load to be fed during Islanding is around 2193 MW (includes 10 MW of defence installations). The current scheme of Chennai was modified and the anticipated generation was reduced to 2512 MW (earlier the anticipated generation was more than 2512 MW). 5.2 MS, SRPC informed that it is an in-service Islanding scheme, and no operational constraints have been reported. The Scheme was last reviewed in May 2021 and TANTRANSCO was asked to complete implementation of the modified scheme within three months. 5.3 TANTRANSCO informed that the modified scheme requires procurement of additional URF relays which is under process. Member (GO&D) advised TANTRANSCO to expedite the process of procurement and complete the scheme in schedule time (by the end of August, 2021). 6. Bangalore Islanding Scheme: 6.1 SE, SRPC informed that this new Islanding Scheme is designed as per the review meeting of Islanding Scheme held on 28.12.2020. It covers major Cities of Bengaluru metropolitan area, Mysore, Kolar & Karwar and strategic/defence installations of Yelahanka , Bengaluru City & Karwar. The Anticipated Generation is around 3905 MW and anticipated Load is 3482 MW. 6.2 The design of the Scheme was completed on 15.07.2021 and is presently under implementation. The scheme is targeted to be put into operation by the end of October 2021. 6.3 KPTCL informed that the additional UFR relays are required at identified substation of PowerGrid, NTPC, KPTCL for implementation of the scheme and the procurement of these relays may take more time. 6.4 Member (GO&D) advised the utilities to expedite the process of procurement and complete the scheme in schedule time i.e by October, 2021. 7. Review of Kolkata Islanding Scheme: 7.1 MS,ERPC informed that Kolkata IS covers the city of Kolkata. The IS have installed capacity of generation around 885 MW and load to be fed during Islanding includes Defence load of 28 MW and critical load of Metro Railways: 10MW, Hospital: 18 MW, Pumping Stations: 28 MW. The strategic location covered under the IS are Fort William, Gun and Shell Factory, Rifle Factory, Ichhapore. 7.2 He further informed that this is an in-service Islanding scheme, and no operational constraints have been reported. The scheme was last reviewed in February 2021. However, healthiness status of the Islanding Scheme is monitored in monthly OCC Meeting of ERPC. 8. Review of Assam Islanding Scheme (IS): 8.1 MS, NERPC informed that the state of Assam has two Islanding Scheme. The Assam-I (or upper Assam) IS covers the loads of Upper Assam system & Deomali Area (Arunachal Pradesh) and it is an in-service Islanding scheme, and no operational constraints have been reported. 8.2 The new IS i.e. Guwahati (Assam-II) Islanding Schemes proposed by NERPC and it covers the loads of Guwahati, Azara, Agia, Boko, Sarusajai, Kahilipara , Narangi, Kamakhya, Dispur, Sisugram, Jawaharnagar. In the Guwahati (Assam-II) Islanding Schemes the load to be fed during Islanding was reviewed to 190 MW (earlier it was 390 MW). The new IS of Assam is under implementation stage. 9. Review and Recommendations 9.1 The Delhi Islanding Scheme would be reviewed within 14 days. 9.2 Member (GO&D) also reviewed the new Islanding Scheme of all the regions . It was informed that based on the Generation, strategic load and schedule availability of generators, the new IS have been designed and prioritized for implementation. 9.3 Member (GO&D) enquired about the healthiness of UFR and advised MS, RPCs to circulate the formats in SOP to state/utilities to get the status of healthiness of relays, communication channel and other equipment and on monthly basis and the same may be forwarded to NPC Division. 9.4 Member (GO&D) also advised MS, RPCs to coordinate for setting up separate display of Islanding Schemes on SCADA of respective states LDCs and RLDCs for real time monitoring of participating generators & critical loads. 9.5 MS, NRPC & MS, WRPC were of the view that the funds from PSDF may be granted to take up for the implementation of new schemes and review of the existing schemes. Member (GO&D) opined that the Islanding Scheme are implemented for the grid security and stability and PSDF fund may be utilized for the same. He requested CE, NPC/MS, RPCs to look into this aspect. ***** Annexure-I List of Participants in the meeting to review the Islanding Schemes of Delhi, Mumbai, Chennai, Bangalore, Kolkata and Assam held on 29.07.2021 through video conference Central Electricity Authority 1. Shri B. K. Arya, Member (GO&D), CEA ……………….(in chair) 2. Smt. Rishika Sharan, Chief Engineer (NPC),CEA 3. Shri R.M. Rangarajan, Director (NPC), CEA 4. Shri Saurabh Mishra, DD (NPC), CEA 5. Shri Himanshu Lal, DD (NPC), CEA 6. Shri Kotthapally Satishkumar, AD (NPC), CEA Southern Region 7. Dr. N. Manjula, MD, KPTCL 8. Shri V. Pannuraj, MD, KPCL 9. Shri A Balan, MS, SRPC 10. Shri Basuraj Goswami, CEO, NTECL 11. Shri Anoop Kumar, ED (SR-I), Powergrid 12. Shri R K Chauhan, ED, HVDC –Engg, PGCIL 13. Shri S Ravi, ED (SR-II), PGCIL 14. Shri Rajendra Kumar Gupta, Site Director, NPCIL 15. Shri S Y Sarwate, ACE (Transmission), NPCIL 16. CEE, SLDC, Karnataka 17. CE, GO, TANTRANSCO 18. Shri Pradeep, KPTCL 19. Shri Uday Trivedi, Vice President, Adani Power 20. Shri Angaru Naresh Kumar, SR II Western Region 21. Shri Satyanarayan S, MS, WRPC 22. ED, MSLDC 23. Shri J K Rathod, SE, WRPC 24. Shri Sachin Bhise, Deputy Director, WRPC 25. Shri K Muralikrishna, WRLDC 26. Shri Juelee Wagh, CE, SLDC, Mahatransco 27. Shri Dilip Devasthale, Adani Power 28. Shri Girish Jawale, Tata Power 29. Shri Pallikuth Devananad, TATA Power 30. Shri Gole Milind, Tata Power Northern Region 31. Shri Naresh Bhandari, MS, NRPC 32. Shri Saumitra Mazumdar, SE(O), NRPC 33. Shri Radhey Shyam Meena, DTL 34. Shri M A Khan, GM, Delhi SLDC 35. Shri Sumit Sachdev, TPDDL Northeastern Region 36. Shri AK Thakur, MS, NERPC 37. Shri Brieflee Lyngkhoi, SE, NERPC 38. CEO, GEC-I, Assam 39. ED, POSOCO, Shillong 40. Shri S.C. Dey, Sr GM, NERLDC 41. Shri C B Thapa, NERLDC 42. Shri Madan Mohan Brahma, CGM, TCC, AEGCL 43. Shri Rajib Sutradhar, POSOCO, Shillong Eastern Region 44. Shri Rabi Chowdhury, MD, CESC Ltd. 45. Shri Sandip Pal, Vice President (System Operation), CESC Ltd. 46. Shri N S Mondal, MS, ERPC 47. Shri D K Jain, ED, ERLDC 48. Shri D K Bauri, SE, ERPC 49. Shri Koushik Banerjee, CESC Ltd. 50. Shri Amaresh Mallick, ERLDC 51. Shri Saugato Mondal, ERLDC 52. Shri Saibal, ERLDC 53. Shri Saurav Kumar Sahay, ERLDC POWERGRID/CTU/POSOCO/ NTPC 54. Shri Ankush Patel, Powergrid 55. Shri Anil Kumar Meena, CTU 56. Shri P.S. Das, CTU 57. Shri Chandan Kumar, POSOCO 58. Shri R Mohan , NTPC Other participants: 59. Shri Lalit 60. Shri Pritam Mukherjee 61. Shri Kishore 62. Shri Jnalwaya 63. Shri Shyamal Konar 64. Shri Salil Saxena 65. Shri Bharat 66. Shri Anil Kumar 67. Shri Rajesh Kumar 68. Shri Som Dutt 69. Shri Preetam Banerjee 70. Shri Ramachandran 71. Shri Dusmanta Bhoi 72. Shri Susovan Das 73. Shri G. Sonowal 74. Shri Yogesh 75. Shri Kangkan Paul 76. Shri Tanuj Baruah 77. Shri Kundala Rajeswar Rao 78. Shri Arunava Sen Gupta 79. Shri Rajesh Bahl 80. Shri Mahamood 81. APDCL, Assam 82. SLDC, Assam ***** HTE KTR/Government of India frya ATET/Ministry of Power h fa fe/Central Electricity Authority T.. THT/National Power Committee Division Ist Floor, Wing-5, West Block-IL, RK Puram, New Delhi-66,e-mail:E Subject: Standard Operating Procedure(SOP) for Islanding Seheme-Keg Ref: MoP letter no. 22-1306/37/2020-OM dated 16h June 2021 In accordance with the above reference of Ministry of Power(MoP), the draft Standard Operating Procedure has been modified and attached at Annexure A. Two islanding scheme of NAPS(NRXAnnexure B) and CESC(ER)(Annexure C) as model schemes also attached for ease of reference. The pointwise reply of the queries/observations raised by MoP is also attached herewith as Annexure Encl: As above. 8fTT /Rishika Sharan) TT 3 (n.A.a.)/Chief Engineer (NPC) Rita Singh,Under Secretary,OM Division, Ministry of Power No. CEA-GO-15-14/4/2021-NPC Division |86-188 Date:2207.2021 Copy to: 1. Chairperson, CEA 2. Member (GO&D), CEA Annexure Queries/Observations of the Ministry on Standard Operating Procedure (SOP) a) Point xiii under the heading "Design Protocol" says, "If there is need to establish a power plant in/around such a city for the purpose, the proposal may be submitted for consideration of the MoP. Possibility of installation of storage system at such location may also be explored." As many important cities may not have adequate capacity of generating stations required for load balancing in the islanding area, this provision may lead to flurry of requests to MoP to establish power plants. I believe the primary responsibility of successful run of islanding scheme lies with the concerned state. Therefore, the request for establishing new power plant should be placed with the state concerned under intimation to MoP. Further, this provision may be suitably qualified for extremely sensitive loads only. CEA Response: Incorporated in the Design Protocol in Item No. 1(vi). b) Point xxviii under the heading "Design Protocol" says, "Wind/solar generating stations, because of their uncertain nature, shall not form part of islanding scheme; hence incoming wind/solar feeders to the substation are to be tripped at Islanding frequency of 47.9 Hz". In this regard it is all right to not take into account wind/solar stations as far as load balancing is concerned in the islanding area. However, at the time of islanding, if solar/wind generators are available, it may help in balancing the load and therefore, tripping of solar/wind feeders necessarily at islanding doesn't seem appropriate. If at the time to islanding, there is need to cut down generation, the solar/wind generation may be the first ones to be disconnected. CEA Response: Islanding Schemes are designed with anticipated load-generation balance and with tripping of predetermined feeders/ ICTs/ generators. The successful operation of Islanding scheme is always doubtful when intermittent and variable generation of wind and solar generation are considered while designing the Islanding scheme. However, the para (xxviii) has been deleted from the Design Protocol. c) Under the heading "Design Protocol" there are 31 sub points. Some issues are repeated across several points. This "Design Protocol" part can be made more concise. CEA Response: 31 points have been concise to 10 points. d) Formats for collection of various information can all be numbered and kept as annexures. CEA Response: Formats were numbered as Format I to V and have been kept as Annexure-II. e) Roles and responsibilities of identified officers, may be by designation, and training protocols may be included in the SoP. CEA Response: i. Role and Responsibilities have been defined and attached at Annexure-III, ii. Training part has been included at S.No 5 under heading “Sensitization and Training of Officers involved” f) A model islanding scheme, one of the better available islanding schemes, may be enclosed for ease of reference. i. The Two islanding scheme of NAPS(NR)(Annexure B) and CESC(ER)(Annexure C) as model schemes attached for ease of reference. *************************************** Annexure A Draft Standard Operating Procedure for Islanding Schemes 1. Design Protocol i. As per Clause 10 of the Central Electricity Authority (Grid Standards), Regulations, 2010: “Islanding Schemes.- (1) The Regional Power Committees shall prepare Islanding schemes for separation of systems with a view to save healthy system from total collapse in case of grid disturbance. (2) The Entities shall ensure proper implementation of the Schemes referred to in subregulation (1).” ii. As per Indian Electricity Grid code amended from time to time, all regional constituents shall ensure that the islanding schemes are always functional. iii. Islanding Schemes may be designed: for survival of some predefined generations and loads at the time of grid disturbance to avoid total blackout and quicker restoration of failed grid. for major cities having loads of VIP areas, Defence, Space, Airport, Metro, ports and important industries etc. iv. Ministry of Defence(MoD) may be consulted to include their defense loads in such Islanding schemes. In case MoD requests any of their locations for which Islanding schemes is to be designed, the same would be considered. Only those defence establishments may be included in the Islanding Schemes for which MoD is agreed. The Ministry of Defence/Dept. of Military Affairs shall furnish information regarding their requirements as per format given at Annexure I. All the existing islanding scheme may be reviewed to include the Defence load in the scheme. Defence load of small capacity (upto 2 MW) not falling under any major cities may be continued with their arrangement of backup supply. v. The Essential loads falling under an Islanding schemes may be taken under consideration while designing Islanding schemes. Generally the essential loads are classified into two categories (i) Super critical Load and (ii) Critical loads. The super Critical load may cover the loads of Defence area, Raj Bhawan, Parliament house, residence of VIPs, Metro rails etc. The Critical loads may consist of loads of hospitals, Airport, Railways, Important Industries etc falling under the area covered in Islanding schemes. The critical and super critical load of the major city may be considered in consultation with the DISCOMs/SLDC and MoD. vi. If there is need to establish a power plant in/around such a city for the purpose, the proposal may be submitted for consideration of the concerned State /Utility under intimation to MoP. Possibility of installation of storage system at such location may also be explored. This provision may be suitably qualified for extremely sensitive loads only. vii. Islanding Schemes are to be formed with anticipated load-generation balance and with tripping of predetermined feeders/ ICTs/ generators. In every islanding scheme, adequate automated mechanism should be implemented for achieving load generation balance in the islanded sub-system. viii. Islanding schemes should not be taken as a system for continued supply to important loads. Necessary arrangement for emergency supply to important critical loads must be made separately. ix. Studies are to be carried out for verifying the operation of the Islanded system. x. The cyber security in the power system for Islanding schemes must be in accordance with the guidelines issued by Government of India. 2. Monitoring of Vital Parameters i. Since formation of Island can take place at any time, monitoring of the following vital parameters, which have a significant role in on successful Island formation, is of paramount interest: a. Anticipated/ actual Generation within the electrical boundary of the Island. b. Anticipated/ actual Load within the electrical boundary of the Island. c. Voltage, Frequency & Power Flows along the peripheral lines which are required to be tripped to form the Island. ii. Above parameters are to be monitored in real-time basis in the Control Room/ Despatch Centre (i.e Sub SLDCs/SLDC/RLDC/NLDC) 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 PMU) at suitable locations within the Island. iii. The data in the formats at Annexures –II (Format I) may be submitted by RLDC/SLDCs to RPCs on monthly basis to certify the healthiness of communication system for monitoring the vital parameters of Islanding Schemes. 3. Certification of Healthiness of Islanding Scheme: i. Since healthiness of an integrated system depends on the healthiness of its constituting components, healthiness of Islanding Scheme has to be ascertained/ ensured by seeking monthly certificate for healthiness of batteries, installed at all Substations located within the electrical boundary of the Islanding Scheme.The idea is since these battery banks provide power supply to Relays, RTUs and PLCC equipment, healthiness of the former is critical to operation of the latter when called for. ii. It is to confirm the healthiness of islanding schemes by participating Generators as well as concerned transmission utilities for their respective portion in the monthly OCC meeting. iii. The data in the formats at Annexures –II (Format II to IV) may be submitted by Generators/Transmission utilities/Discoms etc to RPCs on monthly basis to certify the healthiness of Islanding Schemes. 4. Role and Responsibility and Coordination Activities: i. The Role and Responsibility of the Organizations / Officers/Officials in designing and operating the Islanding Schemes is defined at Annexure-III. ii. This is proposed to be achieved by having a Nodal Officer for each participating Utility in the Island [i.e., those who own assets (Generating stations, substations, transmission lines, distribution lines, etc.) within the Island], and a Chief Nodal Officer from the concerned Despatch/ Control Centre. The Chief Nodal Officer from LDC and Utility- specific Nodal Officers ensure free flow of information among them w.r.t. Islanding Scheme Operational status, and ensure correct & prompt communication between the SCADA Control Centre and various stations (Generating Stations/ Substations). There will be a coordination officer in each region from each RLDCs. iii. An updated list of contact details of all Nodal Officers as mentioned above shall be maintained with LDC & all Utilities involved. The Details of officials as mentioned above may be obtained in the in the Format V of Annexures –II: 5. Sensitization and Training of Officers involved: i. Even though chances of Island formation in a strongly integrated grid are remote, since the Islanding schemes are designed to protect major critical loads/ sensitive generation in the unfortunate event of failing of all other defence mechanisms, The Nodal Officers & concerned field staff associated with O& M of various stations (generating stations as well as substations) within the electrical boundary of the Island should be sufficiently sensitized about the colossal loss of those critical assets on account of Island failure, and consequent disruption to various sectors & businesses. ii. To ensure this, apart from conducting periodic orientation training programmes, the concerned Officers/ staff should also be involved in the activities concerning management of grid under stressed conditions, SCADA control, communication upkeep, and in the activities relating to audit/ inspection of critical loads & sensitive stations within the Island. iii. The Officials and Officers in the Generating Station/Substation/Utilities / LDC/ RLDC / RPCs would be sensitized about the (concerned) Islanding Scheme. They also to be trained to handle the Critical and Emergency Load Management in the system. iv. Training shall be focused on individual Islanding Schemes and integration of Islanding schemes with rest of the grid until restoration of normalcy to the regional grid. v. All the concerned utilities shall organise periodic training program for the nodal officers and concerned field officers. The training programs shall be in consultation and coordination with the RPCs. The training and sensitization program may be conducted once in six months. 6. Periodic Inspection/ Audit of Essential Components: Inspection/ audit of all essential components as given below shall be carried out regularly (by third party) and inspection/Audit report may be submitted to respective RPCs: i. Under Frequency Relays (UFR) on Island forming elements (Lines & ICTs) – Quarterly. ii. Associated communication equipment at all stations within Island - Bi-monthly. iii. Associated DC supply for Control panel & communication system-Bi- monthly. 7. Review Plan of Islanding Schemes: i. Considering the fact that Network Changes (additions/ deletions/ reconfigurations of transmission elements & generators) in an evolving grid such as Indian electrical grid are unavoidable/ inevitable, it is but necessary to review the Islanding scheme operation w.r.t. prevailing grid conditions at regular intervals, and incorporate requisite changes so as to make them reliable & dependable. ii. In such review, all details as used in the existing scheme have to be re-collected including the new changes for studying the modifications to be carried out in the In- service Island. These details, among others, include participating generators, anticipated generation, participating loads, anticipated load, elements (lines and/ or ICT’s) to be tripped to form the modified Island, geographical map & SLD of the modified Island, AUFR load relief, df/dt load relief, pumped loads details, etc. Using these details, system studies also need to be carried out to verify stability (including voltage profile & line loadings profile) of the modified Island. iii. It is recommended to carry out above review of the In-Service Islanding scheme once in six months by all concerned utilities. However, the review may also be carried out as soon as any network change, which may affect the operation of the Islanding Scheme, comes to notice. 8. Identification of Short-comings & Remedial action: Based on the shortcomings noticed as a result of the activities performed in monitoring of vital parameters of the Island, ascertaining healthiness of Island, carrying out periodic inspection/ audit of essential components of the Island, prompt remedial action shall be taken to redress the observed deficiencies. The period of redressal from the instant of noticing shortcomings shall be at most one week/ fortnight. The compliance report may be submitted to RPCs in this regard. 9. Post Islanding survival: In every islanding scheme, adequate automated mechanism should be implemented for achieving load generation balance in the islanded sub-system. Also, for frequency control of islanded subsystem there should be generating units in the island on restricted/ free governor mode of operation. Also, load connection/ disconnection should be possible remotely from the dispatch centre of the islanded sub-system. Health of all facilities in the islanding scheme should be closely monitored so as keep necessary electrical, mechanical, electronics and communication systems in good health all the time. 10. SOP Template for Islanding Schemes is at Annexure-IV ***** Annexure –I MINISTRY OF POWER CENTRAL ELECTRICITY AUTHORITY Details of information to be furnished by Defence installations for the purpose of designing the Electrical Islanding schemes: Item Description Details No. 1 Basic Details: 1.1 Service: Army/Navy/Airforce/MES etc. 1.2 Name of the Establishment 1.3 Location (State, District, Taluk & Village) 1.4 Name of the nearest City & Distance from it 2. Power Supply Details: 2.1 Name of the DISCOM (Power Supply Distribution Company) from which supply is being availed: 2.2 Name of the DISCOM Substation from which supply is being availed: 2.3 Number of incoming lines/feeders of supply and Voltage level 3 Load Details: 3.1 Contracted Capacity in kVA/MVA 3.2 Maximum Demand in kVA/ MVA 3.3 Connected Load in kW/MW 3.4 Critical Load(kW/MW)/ Non Critical Load(kw/MW) 3.5 Any other information on Load details 4 Backup Power Supply: 4.1 Details of DG sets: (Number of DG sets & their Rating in kVA/MVA & No. of hours they can run/sustain) 4.2 Battery Banks/ UPS Rating: 4.3 In-house Solar Generation in kW/MW 4.4 Captive Generation, if any, in kW/ MW 5 Specific Requirement from Ministry of Power, CEA/RPCs, NLDC, RLDC, ST, SLDC and Discoms wrt uninterrupted power supply to Defence installation 6 Other Relevant Information, if any *** Annexure-II Formats for collection of information regarding Islanding Schemes: a. Format - I for RLDC/SLDCs Healthiness of S.NO Name of Islanding Scheme Communication channel b. Format - II for Generating Station Healthiness Healthiness of S.NO Name of Islanding Scheme of Islanding Communication Relay channel c. Format - III for Transmission Utility/ DISCOMs For communication For UFR based tripping logic of based tripping logic Elements feeders of feeders Name of considered Healthiness of Islanding for tripping S.NO Healthiness of PT Fuse and Scheme to from Healthiness of Communication status of DC Island Relay# channel supply to UFR relay* * Where dedicated UFR relay have been installed for tripping of the feeders under islanding scheme # Where UFR function have been enabled within backup protection relay of the line d. Format - IV for collecting Relay details of the Islanding scheme. The following format may be used to get Relay details of the Islanding scheme: S.NO Description UFRs-for df/dt -for Relay for Island load relief load relief creation(C) (A) (B) 1 Relay location (S/s name) 2 Relay make & model 3 Frequency setting of the relay (at which load shedding is envisaged) 4 Feeder name (voltage level and source-destination name) signalled by the Islanding Relay for separation /load shedding/separation from outside grid 5 Quantum of load relief due to tripping of feeder (as per state's peak of previous year) 6 Quantum of load (Min, Avg, Max in MW) on the feeder (as per state's peak of previous year) e. Format - V for Contact details of all Nodal Officers Utility Name Designation Organization Email ID Mobile No. Name &Locat ion *** Annexure –III Roles and Responsibilities of Officers involved in Islanding Schemes: 1. RPCs i. In comply with CEA( Grid Standards) 2010 and its amendments, MS, RPCs shall be responsible for preparation of Islanding Schemes. The designing/ implementation and Review of Islanding Scheme may be discussed in appropriate Committee/Sub-Committee of RPCs or a separate Sub-group may be formed. ii. MS, RPC may Nominate Officer at the level of Superintending Engineer for Coordinating the Islanding Schemes in the Region. iii. MS, RPCs shall be responsible for periodic review of the Islanding Schemes to accommodate the network changes, load generation balance or constraints, if any. iv. MS, RPC shall be responsible for third party audit of the components of an Islanding Scheme. 2. RLDCs i. There shall be a nodal officer at the level of General Manager & above appointed by the appropriate Authority of the RLDC. Nodal officer of RLDCs may act as Coordinating Nodal officer. ii. The Nodal officer of RLDCs shall coordinate the Chief Nodal officers of SLDCs in their respective regions. iii. Coordinating Nodal Officer shall ensure monitoring of the vital parameters of operational/implemented Islanding Schemes in their region, which have a significant role in successful Island formation at their SCADA system. iv. To ensure proper monitoring, measuring instruments (like PMUs etc.) and communication systems may be recommended by Co coordinating nodal officer to the concerned utility. v. Coordinating Nodal officers shall monitor and ensure the healthiness of the components involved in the Islanding Scheme like SCADA system, communication channel etc. at their end. vi. Coordinating Nodal officer shall conduct monthly self- certification of healthiness of the communication systems at their end and communicate it to the concerned RPCs in the format prescribed in the SOP. vii. Coordinating Nodal officer shall ensure follow-up of the recommendation of the third party Audit conducted by RPCs in a time bound manner. 3. Nodal officer of i. There shall be a nodal officer at the level of Chief Engineer LDCs & above for all Islanding Schemes in the respective state appointed by the appropriate Authority of the LDCs. ii. Nodal officer of LDCs shall act as Chief Nodal officers for nodal officers of DISCOMs, TRANSCOS & GENCOs of the state and shall ensure proper communication among all the nodal officers. iii. The Chief Nodal officer shall coordinate and responsible for implementation of newly designed Islanding Schemes in coordinated manner with all utilities involved. iv. Chief Nodal officer is responsible for collection of data from the concerned utilities and submission the same to committee for study purpose in respect of existing/new IS for review/design purpose. v. Chief Nodal Officer shall ensure monitoring of the vital parameters of operational/implemented Islanding Schemes in the state, which have a significant role in successful Island formation. vi. To ensure proper monitoring, measuring instruments ( like PMUs etc.) and communication system etc. may be recommended by nodal officer to the concerned utility vii. Chief Nodal officers shall ensure the healthiness of the components involved in the Islanding Scheme like SCADA system, communication channel etc. at their end. viii. Chief Nodal officer shall conduct monthly self-certification of healthiness of the components at their end involved in the Islanding scheme and communicate it to the concerned RPC in the format prescribed in the SOP. ix. Chief Nodal officer shall ensure follow-up of the recommendation of the third party Audit conducted by RPC in a time bound manner. 4. Nodal officer of i. There shall be a nodal officer at the level of General Manager Participating / Chief Engineer & above for Islanding Schemes appointed GENCOs by the appropriate Authority of the Generation Company. ii. Nodal officers shall be responsible for the implementation of newly designed Islanding Schemes for Genco’s part and submission of data to Study committee wrt Islanding scheme. iii. Nodal officer is responsible for submission of data for Genco part to committee for study in respect of existing/new IS for review/design purpose. iv. Nodal officers shall ensure the healthiness of the components involved in the operational Islanding Scheme like Generating Units, Substations /Switch yards, Relays, communication channel etc. at their end. v. Nodal officer shall conduct monthly self-certification of healthiness the components at their end involved in the Islanding scheme and communicate it to the concerned RPCs in the format prescribed in the SOP. vi. Nodal officer shall ensure follow-up of the recommendation of the third party Audit conducted by RPCs in a time bound manner. 5. Nodal officer i. There shall be a nodal officer at the level of General Manager of / Chief Engineer & above for all the Islanding Schemes STUs/PGCIL appointed by the appropriate Authority of the Transmission Company. ii. Nodal officers shall be responsible for the implementation of newly designed Islanding Schemes at transmission part. iii. Nodal officer is responsible for submission of data to committee for study in respect of existing/new IS for review/design purpose for Transmission part . iv. Nodal officers shall ensure the healthiness of their components involved in the operational Islanding Scheme like Substations, Transmission Lines, Relays, communication channel etc. at their end. v. Nodal officer shall conduct monthly self-certification of healthiness of the components at their end involved in the Islanding scheme and communicate it to the concerned RPC in the format prescribed in the SOP. vi. Nodal officer shall ensure follow-up of the recommendation of the third party Audit conducted by RPC in a time bound manner. 6. Nodal officer i. There shall be a nodal officer at the level of General Manager of DISCOMs /Chief Engineer & above for each Islanding Schemes appointed by the appropriate Authority of the Distribution Company. ii. Nodal officer shall be responsible for identification of essential loads and defence load for the Islanding Scheme. iii. Nodal officers shall be responsible for the implementation of newly designed Islanding Schemes at their end. iv. Nodal officer is responsible for submission of data for their part to committee for study in respect of existing/new IS for review/design purpose. v. Nodal officers shall ensure the healthiness of the components involved in the Islanding Scheme like Feeders, Relays, communication channel etc. at their end. vi. Nodal officer shall conduct monthly self-certification of healthiness of the components involved in the Islanding scheme at their end and communicate it to the concerned RPC in the format prescribed in the SOP. vii. Nodal officer shall ensure follow-up of the recommendation of the third party Audit conducted by RPC in a time bound manner. *** Annexure-IV SOP Template for Islanding Schemes: 1. Purpose 2. Design i. Generation a. Coal b. Gas c. Nuclear d. Hydro e. Solar f. Wind g. Total generation h. PLF or availability /scheduling i. Generation considered j. Generators on prolonged outage k. Probability of the anticipated generation l. Pumped storage? m. ISGS n. SGS o. IPP/MPP ii. Load a. Drinking water b. Irrigation c. Agriculture d. Industrial e. Commercial f. Domestic g. Hospital h. Railways/Metro i. Defence j. Lift Irrigation System/Scheme iii. Load relief a. df/dt-I b. df/dt-II c. AUFR-I d. AUFR-II e. AUFR-III f. AUFR-IV iv. Transmission lines in the islanded area a. 765 kV b. 400 kV c. 220/230 kV d. 132/110 kV e. 66 kV f. 11/22/33 kV g. Inter regional lines h. Inter-state lines i. Intra-state lines o Substations in the area j. CTU k. STU l. ISTS v. Transmission lines that get disconnected on operation of df/dt and AUF relays . 220/230 kV . 132/110 kV . 66 kV . 11/22/33 kV vi. Transmission lines to be tripped for forming Island a. 765 kV b. 400 kV c. 220/230 kV d. 132/110 kV e. 66 kV f. 11/22/33 kV vii. Name of the cities covered a. 10 million b. 1 million c. Defence locations viii. Diagrams a. SLD map of the island b. Geographical map of the island with boundary c. Major cities/critical loads/defence loads marked d. Substations marked 3. SCADA mapping Island generation and island loads on the SCADA display 4. Constraints a. Generation limits b. Line loading limits c. ICT loading limits o Frequency set points d. df/dt-I e. df/dt-II f. AUFR-I g. AUFR-II h. AUFR-III i. AUFR-IV j. LIS relief frequency k. RE generation disconnection frequency l. Islanding frequency 5. Controlling generation in islanded area a. AGC b. RGMO/FGMO i. Controlling load in islanded area a. Automatic b. Flow based c. Voltage based d. Frequency based e. Manual ii. Validation check list . Generation > Load? . Non-Hydro only islanding? . Less number of disconnecting lines? . All disconnecting lines with AUFR? . RE-solar/wind excluded? . LIS loads excluded? . LF studies for islanded area, converging? . In the converged LF studies, line loadings profile & voltage profile are within permissible limits? . All critical load/defence loads included? . Critical/defence loads are not part of SPS, df/dt or AUFR schemes? . Islanding frequency - (47.9 Hz)? . Adequate margin between lower frequency of IEGC band and first stage AUFR? . Adequate margin between islanding frequency and AUFR last stage? . Scheme was discussed & approved in OCC/ PCC? . Scheme approved in RPC? 50.20 50.10 50.05 50.00 IEGC band 49.90 49.80 49.70 Urgent load Mgt. 49.60 49.50 Emergency Load Mgt. 49.40 49.30 49.20 49.10 49.00 UFR load shedding 48.90 48.80 48.70 48.60 48.50 48.40 48.30 48.20 48.10 48.00 47.90 Islanding Frequency 47.80 *** Above values are subject to change as per newly adopted frequency settings in NPC 6. Operation i. Successful . Generation in the islanded area . Load in the islanded area . Date & time island formation . Date & time of island closed/shutdown . Frequency of the islanded area . Voltage profile of the buses . Flows/ Loadings on critical lines . Duration of island survival . Whether anticipated generation was there? . Whether anticipated load was there? . All the lines were disconnected as per the plan? . Reason for islanding success . Any measures to further improve ii. Failure a. Generation in the islanded area b. Load in the islanded area c. Date & time island formation d. Date & time of island closed/shutdown e. Duration of island survival f. Whether anticipated generation was there? g. Whether anticipated load was there? h. All the lines were disconnected as per the plan? i. Reason for islanding failure j. Remedial measures 7. Review plan i. Island formed and approved date ii. Change in generation . Addition . Deletion . Alteration iii. Change in load a. Addition b. Deletion c. Alteration iv. Change of the lines to be disconnected v. Any new lines to be included for disconnecting vi. Requirement of additional df/dt & AUFR relays 8. Nodal officers of Islanding Scheme i. RLDC ii. SLDC iii. STU iv. SGS v. ISGS vi. ISTS (SR-I, SR-II) 9. Sensitization Training of nodal officers i. Training by RLDC ii. Training by NPTI/PSTI iii. Training by SLDC iv. SRPC special meetings 10. Periodic Inspection of Essential components of Islanding Scheme i. Inspection of UF relays of disconnecting lines ii. Ensuring adequate relief under df/dt and AUFR stages iii. Ensuring relays for disconnecting RE sources iv. Ensuring relays for disconnecting LIS v. Ensuring critical/defence loads are not under df/dt & AUFR stages vi. Monitoring the anticipated generation and load in the islanded area 11. Mock drill i. Mock drill to follow any major or near miss incidents ii. Frequent heavy over drawl by states iii. Frequent Very low frequency of operation iv. Before peak period of the region v. Before peak period of the state vi. Loss of many lines due to cyclone/weather vii. Loss of generating plants due to cyclone/weather viii. RE is highest and entirely absorbed by states 12. Certifications of healthiness of IS i. Batteries ii. Relays iii. Lines within the islanded area 13. Identifications of short comings 14. Further updations. ***** Annexure-B 1) Name of the Islanding Scheme (better available): Narora Atomic Power Station (NAPS) Islanding Scheme 2) Brief Working/design of the above Islanding Scheme (with SLD and other details NAPS have two units of 220MW each. The islanding scheme is devised to save the operating unit(s) of NAPS during grid collapse situation. Operating logic for the islanding scheme is as under: a) When One unit is under operation At 48Hz - Low frequency alarm appears in main control room. At 47.9Hz - Four nos. of 220kV feeders are tripped to form NAPS island (feeders are NAPS-Sambhal, NAPS-Atrauli, NAPS-Khurja and NAPS-Dibai). Island load is in the range of 70-90MW of Simbholi S/s and 25MW station load. Frequency further falls to 47.5Hz - All five outgoing lines from NAPS 220kV bus are tripped after 1 sec delay. Station Unit Transformer CBs are tripped after 3 sec delay. Generator Transformer CB are tripped after 5 sec delay. Unit comes on house load. b) When both units are under operation At 48Hz - Low frequency alarm appears in main control room. At 47.9Hz - Two nos. of 220kV feeders are tripped to form NAPS island (feeders are NAPS-Sambhal and NAPS-Atrauli). Island load is in the range of 150-280MW of Simbholi S/s, Khurja S/s and Dibai S/s and 40MW station load. In case, frequency further falls to 47.5Hz - All five outgoing lines from NAPS 220kV bus are tripped after 1 sec delay. Station Unit Transformer CBs are tripped after 3 sec delay. Generator Transformer CB are tripped after 5 sec delay. Units come on house load. SLD for NAPS Islanding scheme is as under: Legends ------220kV level ------132kV level 3) Other data in respect of NAPS IS ------33kV level i. Format (I) for Generating Station Name of Element considered Healthiness of Healthiness of Sl. Islanding for tripping to form Islanding Communication No. Scheme Island Relay channel Self-certification Self-certification to be to be given by 220kV NAPS-Sambhal given by NAPS on NAPS on NAPS Islanding monthly basis 1. monthly basis Scheme 220 kV NAPS-Atrauli -do- -do- 220kV NAPS –Khurja -do- -do- 220kV NAPS-Dibai -do- -do- ii. Format (II) for Transmission Utility/Discoms For communication- For UFR based tripping based tripping logic of feeders Element logic of feeders Name of considered for Healthiness Islanding tripping to form of PT Fuse Scheme Healthiness of Sl. Island and status Healthiness Communication No. of DC of Relay channel supply to UFR relay Self- Self- Self-certification to certification to certification to 220kV Simbholi- be given by be given by be given by Matore UPPTCL on monthly UPPTCL on UPPTCL on basis monthly basis monthly basis 220kV Simbholi – Hapur (765kV) S/S- -do- -do- -do- CKT-1&2 220kV Simbholi- -do- -do- -do- Hapur Hydrid 132kV Simbholi- -do- -do- -do- Hapur 132kV Simbholi- -do- -do- -do- Babu Garh NAPS 132kV Simbholi- -do- -do- -do- 1. Islanding BB Nagar Scheme 132kV Simbholi- -do- -do- -do- Naglikithore ICT-I (160 MvA) at -do- -do- -do- Dibai ICT-II (160 MvA) at -do- -do- -do- Dibai 220kV Khurja- Harduaganj -do- -do- -do- (Double CKT) 220kV Khurja-Dadri -do- -do- -do- 220kV Khurja- -do- -do- -do- Sikandrabad 220kV Khurja- -do- -do- -do- Jahangirabad iii. Format (III): Relay details of the Islanding scheme UFRs (for Sl. df/dt (for Relay for Island Description load No. load relief) creation relief) NAPS, 1 Relay location (S/s name) - - Dibai ABB RXFE-4, 2 Relay make & model - - Alstom MFVUM-12 Frequency setting of the relay 3 (at which load shedding is - - 47.9 Hz envisaged) (i) 220kV NAPS- Feeder name (voltage level SAMBHAL and source-destination name) (ii) 220 kV NAPS-Atrauli signaled by the Islanding (iii) 220kV NAPS –Khurja 4 - - (iv) 220kV NAPS-Dibai Relay for separation /load (v) ICT-I (160 MvA) at shedding/separation from Dibai outside grid (vi) ICT-II (160 MvA) at Dibai Quantum of load relief due to UFR or df/dt load relief is 5 tripping of feeder (as per - - not configured in NAPS state's peak of previous year) IS. Quantum of islanding load Summer min: 108MW (Min, Avg, Max in MW) on the 6 - - Summer avg: 278MW feeder (as per state's last Summer max: 359MW peak) UFRs (for Sl. df/dt (for Relay for Island Description load No. load relief) creation relief) 1 Relay location (S/s name) - - Simbholi 2 Relay make & model - - Alstom MFVUM-12 Frequency setting of the relay 3 (at which load shedding is - - 47.9 Hz envisaged) (i) 220kV Simbholi- Matore (ii) 220kV Simbholi – Hapur (765kV) S/S- Feeder name (voltage level CKT-1&2 and source-destination name) (iii) 220kV Simbholi- signaled by the Islanding Hapur Hydrid 4 - - (iv) 132kV Simbholi- Relay for separation /load Hapur shedding/separation from (v) 132kV Simbholi- outside grid Babu Garh (vi) 132kV Simbholi- BB Nagar (vii) 132kV Simbholi- Naglikithore Quantum of load relief due to UFR or df/dt load relief is 5 tripping of feeder (as per - - not configured in NAPS state's peak of previous year) IS. Quantum of islanding load Summer min: 82MW (Min, Avg, Max in MW) on the 6 - - Summer avg: 110MW feeder (as per state's last Summer max: 149MW peak) UFRs (for Sl. df/dt (for Relay for Island Description load No. load relief) creation relief) 1 Relay location (S/s name) - - Khurja 2 Relay make & model - - Alstom MFVUM-12 Frequency setting of the relay 3 (at which load shedding is - - 47.9 Hz envisaged) (i) 220kV Khurja- Feeder name (voltage level Harduaganj (Double and source-destination name) ckt) signaled by the Islanding 4 - - (ii) 220kV Khurja-Dadri Relay for separation /load (iii) 220kV Khurja- shedding/separation from Sikandrabad outside grid (iv) 220kV Khurja- Jahangirabad Quantum of load relief due to UFR or df/dt load relief is 5 tripping of feeder (as per - - not configured in NAPS state's peak of previous year) IS. Quantum of islanding load Summer min: 26MW (Min, Avg, Max in MW) on the 6 - - Summer avg: 168MW feeder (as per state's last Summer max: 210MW peak) iv. Format IV Contact details of nodal officers Location Officer Email ID Contact No. Sh. H.S. Singh, (STE-E&I), NAPS [email protected] 9412768059 NAPS Ms. Arpita Chakravorty, [email protected] 9412768143 (TE-E) Sh. Indrajeet Singh, SDO, Transmission, UPPTCL [email protected] 9412749987 Simbholi Sh. Sagar Kumar, AE T&C, [email protected] 7290097560 UPPTCL Sh. Mohit Kumar Singh, SDO(T), UPPTCL Dibai [email protected] 7983710548 Sh. Anuj Kumar, AE(T&C), UPPTCL Sh. Mahendra Kumar, SDO(T), UPPTCL Khurja - 7983944373 Sh. Anuj Kumar, AE(T&C), UPPTCL Matore - - - Sh. Aman Kumar, Manager, WUPPTCL [email protected] 9559437270 Hapur 765kV Sh. Sunil Aneja, Testing [email protected] 9355669863 Incharge, WUPPTCL Sh. Aman Kumar, Hapur 220kV [email protected] 9559437270 Manager, WUPPTCL Hybrid [email protected] 9355669863 Sh. Sunil Aneja, Testing Location Officer Email ID Contact No. Incharge, WUPPTCL Sh. H.S. Singh, (STE-E&I), Harduaganj [email protected] 9412768059 NAPS Sh. Devendra Kumar Gupta, SDO(T), UPPTCL [email protected] 7290059691, Dadri Sh. Vipin Kumar, AE(T&C), [email protected] 7290059711 UPPTCL Sh. Amrish Kumar, SDO(T), UPPTCL Sikandrabad [email protected] 9412227558 Sh. Anuj Kumar, AE(T&C), UPPTCL Sh. Mahendra Kumar, SDO(T), UPPTCL Jahangirabad - 9412749904 Sh. Anuj Kumar, AE(T&C), UPPTCL Annexure C Information needed for Islanding Scheme 1) Name of the Islanding Scheme (better available) : Islanding of CESC Generation System 2) Brief Working/design of the above Islanding Scheme (Annexure C2) 3) Other Data Required in respect of the above IS (Logic Diagram attached at Annexure C3) i. Format (I) Format (I) for Generating Station Name of Healthiness of Healthiness of Islanding Islanding Communication Scheme Relay channel S.NO 1 CESC Healthy Healthy ii. Format (II) Format (II) for Transmission Utility/Discoms For communication For UFR based tripping logic based tripping logic of feeders of feeders Name of Feeders Name of S.NO considered for Healthiness of Islanding tripping to form Healthiness of PT Fuse and Scheme Healthiness of Island Communication status of DC Relay# channel supply to UFR relay* (i) EMSS: 132 kV BC1 // 132 kV WBSETCL 1 KASBA F1, F2 & F3. (ii) SRS & Healthiness of BGSS:132 kV PT Fuse and WBSETCL HWH (i) Not Applicable for status of DC F1 at SRS and F2 EMSS supply to UFR Healthiness of CESC & F3 at BGSS// (ii)Communication relay Splitting Relay Generation 132 kV channel between SRS monitored also monitored System WBSETCL HWH & BGSS monitored by locally and from local as Islanding F1, BGSS F2/2A Line Differential Relay also from well as from Scheme & F3 at SRS at SRS remote. remote Annexure C iii. Format (III) : Format (III) : Relay details of the Islanding scheme S.NO Description (A) UFRs (B) df/dt(for (C) Relay for (for load relief) load relief) Island creation 1 Relay location (S/s SRS, ECAL S/S, JAD Not name) S/S, TRS, PLN S/S, Applicable MAJ S/S,BBD BAG S/S 2 Relay make & model Siemens make 7SJ62 & Not Siemens/7SJ62 7RW60 Applicable Alstom Make Micom P923&MFVUM ABB Make FCX 3 Frequency setting of the 47.8 Hz (SRS), 47.7 Hz Not relay (at which load (ECAL), 47.6 Hz (TRS), Applicable shedding is envisaged) 47.5 Hz (PLN), 47.4 Hz(MAJ), 47.3 Hz (BBD BAG) 4 Feeder name (voltage 33kV Feeders Not level and source- Applicable SRS:F.Elgin T1// destination name) Barisha T2, F. signalled by the GRSE // Taratala (W) Islanding Relay for T2, Southern T3, separation /load Kidderpore GIS. shedding/separation from outside grid ECAL: 75 MVA T1 & T2 JAD: F. DhakuriaT2 // Ballygunge T2, Sirity GIS, Tollygunge T1, Jadavpore GIS, TRS: F. Patulia 1, Patulia 2, Panihati GIS, Barrackpore T1 PARK LANE: 50 MVA T1 & 75 MVA T2 MAJERHAT: F. Majerhat T1 & T2, Alipore T1 & T2. BBD BAG: F. Jackson Lane T1, Annexure C F.Strand South GIS, F.Hare St. GIS, F.BBD Bag T1 & T2 5 Quantum of load relief 65 MW (SRS), 70 MW Not due to tripping of feeder (ECAL), 60 MW (JAD), Applicable (as per state's peak of 35 MW (TRS), 65 previous year) MW (PLN), 55 MW (MAJ), 50 MW (BBD BAG) Total : 400 MW 6 Quantum of load (Min, Min. Load: Not Avg, Max in MW) on Applicable 35 MW (SRS), 45 MW the feeder (as per state's (ECAL), 30 MW (JAD), peak of previous year) 20 MW (TRS), 40 MW (PLN), 30 MW (MAJ), 25 MW (BBD BAG) Total : 225 MW Avg. Load: 55 MW (SRS), 60 MW (ECAL), 45 MW (JAD), 20 MW (TRS), 50 MW (PLN), 40 MW (MAJ), 35 MW (BBD BAG) Total : 305 MW Max. Load: 65 MW (SRS), 70 MW (ECAL), 60 MW (JAD), 35 MW (TRS), 65 MW (PLN), 55 MW (MAJ), 50 MW (BBD BAG) Total : 400 MW Annexure C iv. Format IV Format IV :Contact details of all Nodal Officers S/s Name Designation Organization Email ID Mobile No. Name - Mr. Koushik Dy. General CESC Ltd. koushik.banerjee 9007015362 Banerjee Manager @rpsg.in - Mr.Arghya Sr. Manager. CESC Ltd. arghya.ghosal 9831003281 Ghoshal @rpsg.in Annexure-C2 CESC Generation System Islanding Scheme The network of CESC is embedded within WBSETCL system and is connected with the Grid at 132 kV Voltage Level either at Eastern Metropolitan Substation (EMSS) via WBSETCL Kasba Substation or at Southern Receiving Station (SRS) & Botanical Garden Substation (BGSS) via WBSETCL Howrah Substation. CESC System gets islanded from the Grid under the following conditions: - U/F (47.8 Hz for 0.5 secs.) O/F (52.3 Hz for 0.5 secs.) During any fault/disturbance occurring outside CESC network, the islanding scheme gets activated immediately and depending on the fault criticality/system condition, CESC generation system gets isolated from the Grid by the operation of the selected circuit breakers through Split Relay (Logic Diagram enclosed) under the following conditions. Dir. O/C: Stage 1: 500A, Time delay-0.3sec. Stage 2: 800A, Time delay-0.15 sec. Dir. E/F: Stage 1: 250A, Time delay-0.4sec. Stage 2: 500A, Time delay-0.15 sec. U/V with PT fuse fail Blocking: Stage1: 83%, Time delay-0.3sec. Stage2: 70%, Time delay-0.15 sec. Selection of Circuit Breakers for tripping during System islanding is done dynamically so that after System islanding, load generation balance is maintained in islanded system. Logic Diagram for EMSS: Logic Diagram for SRS: Annexure-C3 Eastern Metropolitan Substation (EMSS) : 132 KV NETWORK DISPOSITION WBSETCL WBSETCL I/C2 to WBSETCL KASBA F-1 ECAL 2 KASBA F-2 EMSS (S) KASBA F-3 RESERVE BC 1 BC 2 MAIN 1 MAIN 2 BS 160 MVA I/C1 to 160 MVA 160 MVA PLN 160 MVA PCSS P.ST.SS T-3 EMSS (S) T-2 T-4 T-5 FROM BBGS FROM PGCIL SUBHASGRAM BGSS AND SRS: 132 KV FEEDER DISPOSITION RESERVE BOTANICAL GARDEN MAIN 1 SUBSTATION (BGSS) MAIN 2 BOT//SRS I/C 3 WBSETCL 100 WBSETCL HOW 2 100 MVA T2 BOT//SRS MVA T1 HOW 3 I/C 2//2A WBSETCL 75 MVA 55 MVA 55 MVA MAJ 2 MAJ 1 HOW 1 75 MVA T2 T1 T3 T2 MAIN 1 MAIN 2 SOUTHERN RECEIVING STATION (SRS) TRANSFER Himachal Pradesh State Electricity Board Limited (A State Govt. Undertaking) Registered Office: Vidyut Bhawan, HPSEBL, Shimla-171004. CIN: U40109HP2009SGC031255 Address: SE(lnterstate), HPSEBL, Totu, Shimla-171011 (HP) Phone No. 0177-2838901,0177-2838695 Email address: [email protected], Website:www.hpseb.in No:HPSEBLCE(SOVIS-340(cscWol.xIl/2020/03-OS Dated:27/a 7/241 To The Superintending Engineer, NRPC Secretariat, 18-A, Shaheed Jeet Singh Marg, Katwaria Sarai, New Delhi-110016 Subject: Review of availability of ADHPL Transmission system for the month of August and September 2020- Views of HPSEBL in the matter thereof. Reference: Minutes of Commercial sub-Committee Meeting dated 26.05.2021. Sir, This has reference to the Item No. 10 of Minutes of Commercial sub-Committee held on 13.04.2021 Meeting through video conferencing vide which views of beneficiaries of the ADHPL Transmission from System Prini to Nalagarh are requested in the subject cited matter. In this context is it intimated that under Standard of Performance of Interstate Transmission Licensees (SPITL) 2012 restoration Regulations time need to be within permissible limit however ADHPL took more than 1600Hrs (i.e. 19:30 Hours on to 21.08.2020 15:18 on 30.10.2020) to restore the same. Further HPSEBL agree with the views of Member Secretay, NRPC that it would set precedence for other transmission licensees also. Therefore in HPSEBL view, action in the matter shall oe in line with SPITL review of Regulation 2012, and availability of ADHPL Transmission System shall be denied. Yours sincerely, DA: As above (Moddomeo9/2 Superintending Engineer (Interstate), HPSEBL, Totu, Shimla-171011 Tel.-0177-2838901 [email protected] Copy of the above is forwarded to following for information and necessary action 1. The Chief please Engineer (SO), HPSEBL, Vidyut Bhawan, Shimla 171004. 2. The General Manager (Mkt. Op.), Northern Regional Load Centre Jeet Singh Sansanwal Marg, Katwaria Dispatch (NRLDC), 18-A, Shaheed Sarai, New Delhi-110016. Through E-mail- [email protected] NodalU23181z0 Ofice t/202 Superintending Engineer (Interstate, HPSEBL, Totu, Shimla-171011 Tel. -0177-2838901 [email protected] TTPS SWITCHYARD DISTURBANCE/LINE TRIPPING REPORT – 220KV BASTI LINE 1)DATE AND TIME OF OCCURANCE: 01.08.2021 , 16:51:20 hrs 2)BRIEF DESCRIPTION OF OCCURANCE ALONG WITH FLAG DETAILS: On 01.08.2021 Basti line tripped with following relay operation: AT TTPS END Micom P442 Relay-Broken conductor protection operated, Three phase trip Relay 86T operated. AT BASTI END: N/A 3)ANALYSIS: On viewing the D/R and relay details at TTPS end it is concluded that there was no actual open conductor fault. There was a large unbalanced loading in B phase w.r.t. R and Y phase. hence relay sensed open conductor protection operated condition(Negative phase sequence component of current above the limit w.r.t. Positive sequence component) and given trip command, causing 3 pole tripping of breaker and hence three phase tripping of line happened. Line was in charged condition from remote end. 4)MICOM P442 RELAY FAULT DATA: Broken Conductor trip Ir=197.65A; Iy=152.78A; Ib=116.61KA Vrn=134.1kV;Vyn=135.1kV;Vbn=135.0kV After receiving clearance and synchronizing code from UPSLDC line was synchronized at Tanda end at 17:51:00 hrs on 01.08.2021. 5)REASON OF TRIPPING: Occurrence of Negative phase sequence component(I2) of current above the limit w.r.t. Positive sequence component(I1) due to unbalanced loading in B phase w.r.t. R and Y phase. 8/10/2021 Gmail - NRSS XXXI(B) Transmission Ltd - Submission on NR Operating Procedure 2021-22 NRLDC SO-II NRSS XXXI(B) Transmission Ltd - Submission on NR Operating Procedure 2021-22 Raminder Singh Dear Sir, We are NRSS XXXI(B) Transmission Ltd being an Interstate Transmission Licensee would like to submit suggestion and input on the clause (vii) of 4.4 under Chapter 4 of NR Operating Procedure 2021-22, which states that “In case of 400 kV & above lines tripping on Ph-Ph or 3-phase fault, lines (both end tripping) should not be charge without patrolling and locating the fault using offline fault locator by the owner/Maintenance team. After confirmation from both end utilities & line owner (in format enclosed in Annex-VI (A) confirming the healthiness of both end substation & line protection system) in consultation with RLDC lines is to be taken in-service”: Normally in case where the owners for Transmission lines & substations are two different utilities (which is common in TBCB Assets), the coordination process of doing the Signature Analysis test is a time taking process as it involves the permissions & other testing arrangements to be done at distantly located terminal substations. This time along with the testing time for Signature Analysis will deeply impact the availability of the transmission lines. The above process for Signature Analysis Test ,becomes even more tedious in case where there are multilevel gantries (as in case of PGCIL Kurukshetra & Malerkotla Substations) . For safety precaution during the Signature test in case of Multilevel gantries, shutdown of both incoming & outgoing lines is required to be taken which is a tough proposition. As per the normal practice , the two connecting substations of the lines should provide the Relay Data for the tripping distance immediately to line’s owner & line owner should immediately start the patrolling in the mentioned & nearby sections. After finding the fault & necessary remedial action, the patrolling report shall be immediately shared with the substations with a permission request for charging the line. Hence keeping in view, the above-mentioned points, it is requested that in case of a phase-to-phase fault or a 3-phase fault, one attempt for charging the lines should be provided to line’s owners after receiving patrolling report from the line’s owner. Thanks & regards, https://mail.google.com/mail/u/1?ik=0ca93a6a7a&view=pt&search=all&permmsgid=msg-f%3A1706697133438190490&simpl=msg-f%3A1706697133438190490 1/1 India Grid Trust Ref No: - IGT/R&C/21-22/102 Date: 04/08/2021 To, Member Secretary Northern Regional Power Committee 18-A, Qutab Institutional Area, Shaheed Jeet Singh Marg, Katwaria Sarai New Delhi- 110016 Kind Attention: - Sh. Naresh Bhandari Sub.- Regarding Clause 4.4 (viii) of Operating Procedure for Northern Region, July 2021 in compliance with Regulation 5.1 (f) of IEGC. Dear Sir, This is with reference to recently convened 185th OCC meeting held on 20.07.2021 regarding the operating procedure for Northern Region to be implemented in FY 22. This operating procedure was listed at Agenda item no. 15 of the OCC meeting, during the discussion of draft operating procedure, inputs were sought from the transmission licencees and other utilities. During the course of discussion IndiGrid representative along with other constituents raised a concern over the provisions laid down / recorded at Clause No. 4.4 (viii), the same has been reiterated hereunder for ease of reference: “In case of 400 kV & above lines tripping on Ph-Ph or 3-Phase fault, lines (both end tripping) should not be charged without patrolling and locating the fault using offline fault locator by the Owner/Maintenance team. After confirmation from both end utilities & line owner (in format enclosed in Annex-VI (A) confirming the healthiness of both end substation & line protection system) in consultation with RLDC lines is to be taken in-service” With respect to above, we would like to submit our opinion of the matter as below. 1. IndiGrid had opined that aforementioned clause has an adverse incremental impact on the restoration time of the transmission line element and requires further detailing in terms of treatment of this increase in time of outages due to use of Offline fault locators which in turn impact the availability and tariff of the licensee. Based on the inputs received from all the power utilities and after considering the discussion, SE(O) NRPC advised to all the concerned constituents to submit their views and concerns on the operating procedure through written submissions. 2. Accordingly, we would like to draw your kind attention towards the fact that during the regular operating procedure phase – phase faults in a transmission line element, generally are seen to be of transient in nature. As per the prudent practices, O&M team in case of such tripping, resulting out of aforementioned faults, carry out a thorough investigation of the affected / impacted region of the line and carry out a detailed analysis based on the historical datum of such events of that line element. The charging clearance thereafter is given after analyzing all these parameters. Here it is pertinent to mention that usage of Offline Fault Locators in such events though provides an additional check mechanism over the prudent practice of patrolling of line, but also impacts the outage time substantially along with other related commercial issue. Hence, this additional time impact must be suitably factored into Principal Place of Business & Corporate Office: Unit No101, First Floor, Windsor, Village Kole Kalyan Off CST Road, Vidyanagari Marg, Santacruz (East), Mumbai, Maharashtra-400098, India Email: [email protected] |www.indigrid.co.in | Ph: +91 70284 93885 India Grid Trust the process of restoration and a mechanism is required to be introduced in terms of usage of Offline Fault Locators which, it seems, need a little more deliberation in the Standard Operating Procedure. Apart from the above, the possibility of relay malfunctioning at any of the substation ends can’t also be ruled out in case of phase-to-phase trippings. This can be substantiated by looking at the following example of our NRSS project: In one of our recent tripping on 10.06.2021 in 400 kV Jalandhar - Sambha transmission line both circuits were tripped with relays indicating phase to phase fault. Whereas, on investigation and patrolling it was found that the tripping was on account of phase to ground fault. Further, it was also identified that the spot of tripping and the location sensed by relay were 5 kms apart from each other, resulting in a thorough patrolling of the complete stretch which consumed both substantial time as well as efforts. Such events are very common in transmission line elements and with the usage of Offline Fault Locator might further increase the restoration time as the relay has sensed phase to phase one and the actual condition in different. 3. Further, in transmission line configurations where substations are not in purview of the transmission licensee, the process might lead into coordination issues thus making the process all the more difficult and lengthier. The reliability of the grid also gets impacted due to this increase in time of outage of transmission line element due usage of Offline Fault Locators, in view of the same a suitable process should be developed by NRLDC so that the restoration of line in case such trippings are encountered, can be reduced without keeping a healthy line out of operation. 4. In addition to the above, introduction of this process of checking of transmission line post tripping through usage of Offline Fault Locators, prior to restoration, shall also require the following to be ensured: i. Every substation should be equipped with offline fault locator. ii. Inclusion of fault locator shall require a capacity building process and shall take considerable time. A competent manpower also needs to be stationed for proper operation of the equipment. 5. The gravity of impact on Grid Stability can be understood with help of below mentioned examples from some of our transmission line elements which are crucial to the system: i. PKTCL (Parbati-Koldam) is the only source of power evacuation of 1420 MW (Parbati - III 520 MW, Parbati -II 800 MW & Sainj HEP – 100 MW) & during the period of checking, entire/part generation may remain out causing generation loss. ii. Further, NRSS, PKTCL are passing through hilly terrain and access to tower locations are difficult, hence at least one trial (in confirmation with Line Team) before declaring a permanent fault one is suggested. 6. We suggest that the time duration from line being declared fit for charging by licensee between the event should not be attributed to the line owner and should be considered as deemed available/system constraint if the line is getting successfully charged. The additional Principal Place of Business & Corporate Office: Unit No101, First Floor, Windsor, Village Kole Kalyan Off CST Road, Vidyanagari Marg, Santacruz (East), Mumbai, Maharashtra-400098, India Email: [email protected] |www.indigrid.co.in | Ph: +91 70284 93885 India Grid Trust time required for checking through offline fault locator we suggest it should not be made accountable to transmission licensee’s down time. In view of the foregoing, it is submitted that the clause should be appropriately modified to reduce the operational and commercial impact on the transmission licensee and provide a suitable mechanism on the allocation of outage hours arising out of checking the healthiness via Offline Fault Locator. It is also suggested that a provision for test charging can be given after line maintenance team provides its healthiness to eradicate the complications arising out of use of offline fault locator. We request your good self to kindly take note of our concerns and suggest to incorporate suitable amendments accordingly. Looking forward for your kind cooperation. Yours’s Faithfully, For India Grid Trust I R Venkatraman (Vice President, Regulatory & Contracts) CC To: 1. SE (O), Northern Regional Power Committee, 18-A, Shaheed Jeet Singh Marg, Katwaria Sarai, New Delhi-110016. 2. In-charge, Northern Region Load Dispatch Center, 18-A, Shaheed Jeet Singh Marg, Katwaria Sarai, New Delhi-110016 Principal Place of Business & Corporate Office: Unit No101, First Floor, Windsor, Village Kole Kalyan Off CST Road, Vidyanagari Marg, Santacruz (East), Mumbai, Maharashtra-400098, India Email: [email protected] |www.indigrid.co.in | Ph: +91 70284 93885 Annexure-B.I.c Comments by NR-1 on Draft Changes in Grid Operating Procedure for Northern Grid_2021-22 _ Proposed by NRLDC Sl. No. Existing Procedure Draft/Proposed Change OBSERVATION & SUBMISSION 1 Chapter-3 (Para3.2):- Addition: Practice of D-3 is already Shutdown requisitions It also be noted that, while being followed for all Shut approved by NRPC/OCC applying for outages, down of main Grid elements shall be forwarded to NRLDC indenting agency needs to i.e. Line/ ICT/ Reactor/ Buses/ at least 3 days prior ensure the HVDC etc. to facilitate processing time for to the date on which the healthiness of DIA to coordination among RLDC/ shutdown is to be availed. If which the transmission element is connected. i.e., SLDC/ Utilities etc. any deviation is required, the same shall be in case of One and half CB scheme, other List of planned Bay SD is with prior permission of side DIA and for DMT already being submitted to NRLDC. Requisitions for OCC for approval and availed scheme healthiness of TBC shutdown timing shall be with due information to needs to NRLDC. planned properly and be intimated. The shutdown works shall be completed of associated transmission Applying bay SD on D-3 basis within approved shutdown and generation elements timings. and follow up for approval e.g. Bus will additionally engage for bar, Circuit breaker, etc. message exchange and put shall also be routed through pressure on control room staff planned outage co- without any real benefit in the ordination. In grid operation. case of any emergency only as mentioned in IEGC 5.2 More over opening of a Bay (b), the switching operation within Substation does not may affect main element power be carried out and shall be flow without any involvement intimate to NRLDC as of other station/ utility. early as possible. (Subject to the approval of next OCC) AMP of CB etc is routine exercise and considering number of 400kv and 220kv breakers in system, there will be difficulty in rescheduling of bay SD as it will affect other maintenance activities for maintaining healthy grid elements. However SD of Bays/ Bus/ Filter bank and FSC etc within a substation (Not affecting Power Flow) may be applied on D-1 basis and approved accordingly. 2 Chapter-3, Para3.2.2. Final Changes/ Addition Rescheduling of approved approval from NRLDC: Proposed: Outages within the same month In line with the regulation In the event of any shall be allowed as per existing 5.7.4 (i) of IEGC, each user, requirement to re-schedule practice. Further in case of any CTU and STU in Northern any planned shutdown or to valid reason due to system or Site constraint, ROW issue, Region shall avail an emergency / unforeseen shutdown not T&P mobilization, overlapping obtain the final approval in period or other force majeure the form of an ‘Operation anticipated earlier, the concerned entity shall condition, the same shall code’ for an important grid st forward a request to remain valid till 1 week of element of NR continuing month. NRLDC indicating the from NRLDC prior to nature of emergency or the availing an outage. Fresh NRPC consent shall be reason for deferment. required for any rescheduling Telemetry/data at NRLDC of NRLDC would approve element undergoing of shutdown dates beyond such unforeseen outages / above period. Such shutdown shutdown would be ensured re-scheduling of an already by the respective agencies may be applied to NRLDC on planned outage based on D-3 basis for consideration while requesting for operation the exigency of the subject to NRPC approval. code from case vis-à-vis system NRLDC. All preparatory conditions. In case, any Any urgent nature of Shutdown works for maintenance must planned shutdown spill due to emergency condition/ be done well in advance over to the near by date or unforeseen circumstances or before availing the before OCC, the same Realy protection testing etc code so as to avoid any idling would again need approval shall be allowed by NRLDC time. Such requests shall be from NRPC for the next considering real time system forwarded to the NRLDC planned date through constraints as per approved control room email/letter. In other case, operating procedure without sufficiently in advance so as it have to brought in need of NRPC consent. to provide adequate time for upcoming Operation Co- carrying out the adjustments ordination Committee in the (OCC) by the concerned network/despatch (if required) entity for further approval. for facilitating the outage. In both the cases, the Similarly, an ‘Operation concerned entity would code’ would have to be intimate NRLDC three days prior as per the obtained from NRLDC before approved outage procedure. reviving the element after shut down. Telemetry availability & reliability must be ensured by the respective agencies while requesting of operation code for revival of element after shutdown. 3 Chapter-4 (Para4.3):- Existing Para deleted with Provision must continue. In respect of double main and following transfer switching scheme at Change: Opening of a Bay within 400 kV substations, NRLDC Any switching operation on Substation does not affect shall be imp grid element (bay main element power flow elements also) would without any involvement of informed whenever the 400 required operation code from other station/ utility. kV transfer breaker at any NRLDC. substation is utilized for AMP of CB etc is routine switching any exercise and considering line/ICT. In a 400 kV & number of 400kv and 220kv above substation/power breakers in system, there will station switchyard having be difficulty in rescheduling of breaker and a half bay SD as it will affect other switching scheme, outage maintenance activities for maintaining healthy grid within the substation (say elements. main or tie circuit breaker) not affecting power However SD of Bays/ Bus/ flow on any line/ICT may be Filter bank and FSC etc within availed by the a substation (Not affecting constituents/agencies after Power Flow) may be applied intimating to NRLDC. on D-1 basis and approved However, while availing such accordingly. shutdowns or carrying out switching operations it must be ensured that at least two Dias are complete even after such outage from the view point of network reliability. Any outage not fulfilling the above conditions needs the approval of NRLDC. 4 Chapter-4 (Para4.4)viii:-In Changes/ Addition Line healthiness and its case of 400 kV & above lines Proposed: availability is a paramount tripping on Ph-Ph fault, lines In case of 400 kV & above concern to its owner/utility and (both end tripping) should not lines tripping on Ph-Ph or 3- due care with analysis is taken charge without patrolling and phase fault, lines (both end before asking the charging clearance in such cases. offline fault locator by the tripping) should not be charge without patrolling Further, the reasons for owner/Maintenance team. majority of such tripping have and locating the fault using After been found temporary in offline fault locator by the confirmation from both end nature without involving any utilities in consultation with owner/Maintenance team. line hardware etc. that is due RLDC lines to be taken in- After confirmation from to kite thread/ lightening/ service. both end utilities & line swinging of conductor during owner (in format enclosed abnormal weather as per in Annex-VI (A) confirming previous records. the healthiness of both end Utilities are well versed with substation & line protection all these situation/constraint system) in consultation with therefore one charging must be RLDC lines is to be taken in- allowed after obtaining service. request/ clearance form utility as per current practice. In case of failed attempt, the utility shall ensure due patrolling and rectification of problem, if any before asking for charging clearance. National Load Despatch Centre Import of Uttar Pradesh Transfer Capability for September 2021 Issue Date: Issue Time: Revision No. 0 Long Term Margin Available Total Transfer Access (LTA)/ Available for Changes in Time Period in Reliability Transfer Date Capability Medium Term Short Term TTC w.r.t. Comments IST (hrs) Margin (MW) Capability (TTC) (MW) Open Access Open Access Last Revision (ATC) (MW) (MTOA) (MW) (STOA) (MW) https://www.upsldc.o 1st September rg/documents/20182/ 2021 to 30th 0/ttc_atc_24-11- 00-24 13800 600 13200 7200 6000 September 16/4c79978e-35f2- 2021 4aef-8c0f- 7f30d878dbde Limiting Constraints N-1 contingency of 400/220kV Sohawal (PG), Gorakhpur (UP), Sarnath, Obra and Lucknow(PG) ICTs 80% of LTA/MTOA/ISGS allocation capacity considered to account for machine outages National Load Despatch Centre Import of Rajasthan Transfer Capability for September 2021 Issue Date: Issue Time: Revision No. 0 Long Term Margin Available Total Transfer Access (LTA)/ Available for Changes in Time Period in Reliability Transfer Date Capability Medium Term Short Term TTC w.r.t. Comments IST (hrs) Margin (MW) Capability (TTC) (MW) Open Access Open Access Last Revision (ATC) (MW) (MTOA) (MW) (STOA) (MW) https://sldc.rajas 1st September than.gov.in/rrvpn 2021 to 30th 00-24 6200 300 5900 3600 2300 l/scheduling/dow September 2021 nloads Limiting Constraints N-1 contingency of 400/220kV Chittorgarh, Jodhpur ICTs and Ajmer ICTs 80% of LTA/MTOA/ISGS allocation capacity considered to account for machine outages National Load Despatch Centre Import of Haryana Transfer Capability for September 2021 Issue Date: Issue Time: Revision No. 0 Long Term Margin Available Total Transfer Access (LTA)/ Available for Changes in Time Period in Reliability Transfer Date Capability Medium Term Short Term TTC w.r.t. Comments IST (hrs) Margin (MW) Capability (TTC) (MW) Open Access Open Access Last Revision (ATC) (MW) (MTOA) (MW) (STOA) (MW) 1st September https://hvpn.org. 2021 to 30th 00-24 8500 600 7900 4300 3600 in/#/atcttc September 2021 Limiting Constraints N-1 contingency of 400/220kV ICTs at Deepalpur and Kurukshetra(PG) 80% of LTA/MTOA/ISGS allocation capacity considered to account for machine outages National Load Despatch Centre Import of Delhi Transfer Capability for September 2021 Issue Date: Issue Time: Revision No. 0 Long Term Access Margin Available Total Transfer (LTA)/ Medium Available for Changes in Time Period in Reliability Transfer Date Capability Term Open Short Term TTC w.r.t. Comments IST (hrs) Margin (MW) Capability (TTC) (MW) Access (MTOA) Open Access Last Revision (ATC) (MW) (MW) (STOA) (MW) 1st September 2021 to 30th 00-24 6800 300 6500 3800 2700 September 2021 Limiting Constraints N-1 contingency of 400/220kV Mundka and Bamnauli ICTs. 80% of LTA/MTOA/ISGS allocation capacity considered to account for machine outages National Load Despatch Centre Import of Delhi Transfer Capability for September 2021 Issue Date: Issue Time: Revision No. 0 Long Term Access Margin Available Total Transfer (LTA)/ Medium Available for Changes in Time Period in Reliability Transfer Date Capability Term Open Short Term TTC w.r.t. Comments IST (hrs) Margin (MW) Capability (TTC) (MW) Access (MTOA) Open Access Last Revision (ATC) (MW) (MW) (STOA) (MW) https://www.pun 1st September jabsldc.org/down 2021 to 30th 00-24 7400 600 6800 4860 1940 loads/ATC- September 2021 TTC0321.pdf Limiting Constraints N-1 contingency of 400/220kV Rajpura, Nakodar and Ludhiana ICTs. 80% of LTA/MTOA/ISGS allocation capacity considered to account for machine outages National Load Despatch Centre Import of Delhi Transfer Capability for September 2021 Issue Date: Issue Time: Revision No. 0 Long Term Access Margin Available Total Transfer (LTA)/ Medium Available for Changes in Time Period in Reliability Transfer Date Capability Term Open Short Term TTC w.r.t. Comments IST (hrs) Margin (MW) Capability (TTC) (MW) Access (MTOA) Open Access Last Revision (ATC) (MW) (MW) (STOA) (MW) 1st September https://hpsldc.co 2021 to 30th 00-24 500 100 400 m/mrm_category September 2021 /ttc-atc-report/ Limiting Constraints N-1 contingency of 400/220kV Nallagarh ICTs and loading of 220kV Nallagarh-Uperanangal D/C 80% of LTA/MTOA/ISGS allocation capacity considered to account for machine outages Annexure-B.IV Outa S. Outage Date and Element Name Type Owner ge Reason / Remarks No` Time days A LINE Due to heavy land slide near village Dalwas at Ramban damages 220 KV Kishenpur(PG)- occurred to 220 KV D/C 31-03- 1 Ramban(PDD) (PDD) Ckt-Line PDD JK 16:43 455 KPTL at Location No :- 2020 1 187,188 &189 and there is every apprehension of collapsing Tower Loc No 189 . B BUS & BAYS 202 MAIN BAY - 220KV For termination of 220 BUS 1 AT POWER 23-02- kV Ajijpur-Paina 1 BAY 10:19 137 SHAHJAHANPUR(PG) GRID 2021 Line(New UPPTCL line) (POWERGRID) with bay 202 203 MAIN BAY - 220KV For termination of 220 BUS 1 AT POWER 23-02- kV Ajijpur-Paina 2 BAY 10:19 137 SHAHJAHANPUR(PG) GRID 2021 Line(New UPPTCL line) (POWERGRID) with bay 203 For Erection of CT Isolator Breaker IPS 714 TIE BAY - 765/400 KV tube ii) Testing & 1500 MVA ICT 3 AT POWER 04-06- 3 BUS 10:19 38 commissioning of JHATIKARA(PG) AND GRID 2021 switchyard equipments FUTURE i.e Isolator CT Breaker (OCC-183) 713 MAIN BAY - 765 KV POWER 05-04- Major Annual 4 BHADLA(PG) - BUS 1 AND BAY 09:43 98 GRID 2021 Maintenance. FUTURE AT BHADLA(PG) Bay Extension work of 702 Tie Bay with 765 kV POWER 05-04- 5 BAY 09:43 98 Bikaner Khetri Anpara-D TIE BAY - GRID 2021 765/400 KV 1000 MVA Transmission Limited. ICT 1 AT UNNAO(UP) (UPPCL) AND FUTURE AT 765 KV UNNAO(UP) (UPPCL) E/S/D taken due to abnormal humming sound observed from 400 KV Kadarpur (GPTL) - 17-04- 6 BUS GPTL 13:18 85 400KV B-phase BUS-1 Bus 1 2021 CVT at Kadarpur. Replacement of VT pending. 401 MAIN BAY - 400KV Damage of R-phase ANPARA_B(UPUN)- 22-06- post insulator of 7 BAY UPPTCL 16:29 19 MAU(UP) (UP) CKT-1 AT 2021 pantograph isolator Mau(UP) connected to Bus-2. Discussion in 185 OCC S.No Element Name Type Owner Outage Reason / Remarks Outage Meeting days C ICT 400/220 kV 315 12- Oil leakage in _ 1 MVA ICT 1 at ICT RRVPNL 05- 23:42 791 transformer. Expected Bhilwara(rs) 2019 revival in Dec-2021. Buccholz relay alarm _ and Local Breaker Backup protection operated. Tripped along 400/220 kV 315 13- with Hapur-Muradnagar 2 MVA ICT 1 at ICT UPPTCL 03- 02:46 486 line. Flags are not reset Muradnagar_1(UP) 2020 because of cable flashover. To be replaced by 500 MVA ICT. Expected revival in May-2021. 400kV side B-phase bushing blasted. 400/220 kV 315 30- Tripped on differential 3 MVA ICT 2 at ICT DTL 03- 17:35 103 protection, REF Bawana(DV) 2021 protection. ICT catches fire and damaged. 500 MVA ICT-I also got 400/220 kV 500 19- damaged due to fire in 4 MVA ICT 2 at ICT UPPTCL 08- 16:30 327 ICT-II, for protection Noida Sec 148(UP) 2020 testing. Expected revival in June-2021. R-phase HV (400kV) & ICT is 400/220 kV 315 22- MV (220kV) Bushing of expected 5 MVA ICT 2 at ICT UPPTCL 03- 15:51 111 315 MVA ICT-2 got this month Orai(UP) 2021 damaged at 400 KV S/S ORAI. 400/220 kV 315 20- 6 MVA ICT 2 at ICT DTL 09- 00:419 661 Due to fire in ICT. Mundka(DV) 2019 220/33 kV 125 27- MVA ICT 1 at Saurya Operation of 7 ICT 05- 23:42 47 Saurya Urja Urja transformer protection 2021 Solar(SU) Discussion D BUS REACTORS in 185 OCC Meeting Flashover/Fault in 80 MVAR Bus Reactor 80MVAR Bus Reactor 17-10- 1 No 1 at 400KV BR SJVNL 12:58 633 cleared by Bus Bar 2019 Nathpa Jhakri(SJ) Protection. Expected revival in Nov-2021. 125 MVAR BUS REFURBISHMENT OF REACTOR NO 3 AT POWER 04-06- COMMON SYSTEM AND 2 BR 21:52 37 400KV GRID 2021 CONTROL AND VINDHYACHAL(PG) PROTECTION OF NORTH SIDE BUS REACTOR AR4 UNDER ADD CAP (OCC 183) REFURBISHMENT OF COMMON SYSTEM AND 125 MVAR BUS CONTROL AND REACTOR NO 4 AT POWER 04-06- 3 BR 21:52 37 PROTECTION OF NORTH 400KV GRID 2021 SIDE BUS REACTOR AR4 VINDHYACHAL(PG) UNDER ADD CAP (OCC 183) REFURBISHMENT OF COMMON SYSTEM AND 93 MVAR BUS CONTROL AND REACTOR NO 2 AT POWER 04-06- 4 BR 21:52 37 PROTECTION OF NORTH 400KV GRID 2021 SIDE BUS REACTOR AR4 VINDHYACHAL(PG) UNDER ADD CAP (OCC 183) REFURBISHMENT OF COMMON SYSTEM AND 93 MVAR BUS CONTROL AND REACTOR NO 1 AT POWER 04-06- 5 BR 22:40 37 PROTECTION OF NORTH 400KV GRID 2021 SIDE BUS REACTOR AR4 VINDHYACHAL(PG) UNDER ADD CAP (OCC 183) Discussion E HVDC POLE in 185 OCC Meeting REFURBISHMENT OF 70 KV 20- HVDC BLOCK#2 UNDER HVDC 1 VINDHYACHAL(PG) POWERGRID 04- 09:35 83 O&M ADD CAP vide POLE POLE-2 2021 CERC Petition 543/TT/2014 (OCC-181) H` GENERATING UNITS Outage Discussion in 185 Outag Outag duratio OCC Meeting S.No Station Owner Outage Reason e Date e Time n(in days) 126 MW Renovation and 01-04- 1 Bhakra HPS - BBMB Maintenance work. 09:20 804 2019 Unit 3 Expected by July-2021. 126 MW Renovation and 01-04- 2 Bhakra HPS - BBMB Maintenance work. 09:20 804 2019 Unit 7 Expected by July-2021 500 MW UPPTC Generator blast due to 13-11- 3 Anpara-D TPS 14:14 577 L hydrogen leakage. 2019 - unit 2 Excessive leakage in 40 MW Sewa- HRT between audit-II 25-09- 4 II HPS - UNIT NHPC 00:00 261 and Dam. Expected by 2020 2 Jan-2022. Excessive leakage in 40 MW Sewa- HRT between audit-II 25-09- 5 II HPS - UNIT NHPC 00:00 261 and Dam. Expected by 2020 3 Jan-2022. Excessive leakage in 40 MW Sewa- HRT between audit-II 25-09- 6 II HPS - UNIT NHPC 00:00 261 and Dam. Expected by 2020 1 Jan-2022. 600 MW Capital Overhauling. RGTPP 02-03- 7 HVPNL Expected date to be 00:00 103 (Khedar) - 2021 confirmed from HVPNL. UNIT 2 Renovation and 60 MW modernization of unit. 27-11- 8 Bairasiul HPS - NHPC 10:00 198 Expected by September 2020 UNIT 3 2021 165 MW Penstock inspection. 28-10- 9 Dehar HPS - BBMB 11:50 228 Expected by July 2021. 2020 UNIT 3 On test run on full schedule from 16:38 of 11/07/21. 165 MW Penstock Inspection. Expected around 28-10- 10 Dehar HPS - BBMB Expected by 15-July 11:50 228 5th Auh 2020 UNIT 4 2021. 200 MW Turbine Problem TG 16-03- 11 Singrauli STPS NTPC BRG VIBRATION HIGH. 11:43 119 2021 - UNIT 3 Expected by July 2021. 660 MW Due to abnormal sound Expected in last 27-02- 12 Talwandi Sabo PSPCL in boiler. Expected by 19:34 140 week of July 2021 TPS - UNIT 3 July-2021 660 MW Expected by 24 Chhabra RRVPN Annual Shutdown. 01-04- Jul 13 00:05 107 SCTPS - UNIT L Expected by July-2021. 2021 5 Outage Outage Sr No Element Name Reason Date Time 11-Jul-21 17:50 Y-B fault. As per PMU, Y-B fault is observed. 1 400 KV Bareilly-Meerut (PG) Ckt-1 24-Jul-21 11:51 Y-B fault. As per PMU, Y-B fault is observed. 25-Jul-21 11:20 Y-B fault. As per PMU, Y-B fault is observed. 20-Jul-21 06:01 Over voltage. As per PMU, No fault observed. Y-N fault. As per PMU, Y-N fault and unsuccessful auto- 2 400 KV Orai-Mainpuri (UP) Ckt-2 27-Jul-21 05:12 reclosing observed. 27-Jul-21 06:57 Over voltage. As per PMU, No fault observed. Directional Earth Fault relay operated. As per PMU, No fault 12-Jul-21 12:09 observed. 3 400/220 kV 240 MVA ICT 3 at Obra_B(UP) 15-Jul-21 09:17 86A and 86B optd. As per PMU, No fault observed. Differential protection phase Y, B, 86. As per PMU, Y-B fault 31-Jul-21 23:11 is observed. 01-Jul-21 17:15 R-Y fault. As per PMU, R-Y fault is observed. 03-Jul-21 16:58 Y-N fault. As per PMU, No fault observed. R-N fault , Fault current 5kA, Dist. 28.8km from Zainkote end 220 KV Amargarh(NRSS XXIX)-Ziankote(JK) (PDD 11-Jul-21 08:38 (Fault was in 220KV Alusteng - Zainkote -2 line). As per PMU, 4 JK) Ckt-2 No fault observed. B-N fault. As per PMU, B-N fault occured, no auto-reclosing 17-Jul-21 12:55 observed. 31-Jul-21 21:33 B-N fault. As per PMU, No fault observed. Line-1 CB of Singoli end tripped due to under voltage (B and 08-Jul-21 15:36 C phase) stage-2 protection operated. VBN: 95.59 kV, VCN: 93.77 kV. As per PMU, No fault observed. Tripped due to DT received from Srinagar end. As per PMU, 20-Jul-21 14:39 Y-N fault occured, no auto-reclosing observed. 28-Jul-21 14:38 Y-B fault. As per PMU, Y-B fault is observed. 220 KV Singoli Bhatwari(Singoli(LTUHP))- 5 Srinagar(UK) (PTCUL) Ckt-1 400 KV Alaknanda-Srinagar-1 tripped at the same time. Tie- bay CB blast of B-phase at Alaknanda reported. Line-2 tripped at under voltage stage 2 reported by Singoli. All 03 29-Jul-21 16:31 units at Singoli and 01 unit at Alaknanda also tripped.Line-1 tripped due to under voltage stage2 as reported by Singoli. As per PMU, B-N fault occurred and delayed clearance of 280ms with no auto-reclosing observed. Line-2 CB of Singoli end tripped due to under voltage (B and 08-Jul-21 15:36 C phase) stage-2 protection operated. VBN: 95.39 kV, VCN: 93.89 kV. As per PMU, No fault observed. Tripped due to DT received from Srinagar end. As per PMU, 20-Jul-21 14:39 Y-N fault occured, no auto-reclosing observed. DT received from Srinagar end. As per PMU, Y-B fault is 220 KV Singoli Bhatwari(Singoli(LTUHP))- 28-Jul-21 14:38 6 observed. Srinagar(UK) (PTCUL) Ckt-2 400 KV Alaknanda-Srinagar 1 tripped at the same time. Tie- bay CB blast of B-phase at Alaknanda reported. Line-2 29-Jul-21 16:31 tripped at under voltage stage 2 reported by Singoli. All 03 units at Singoli and 01 unit at Alaknanda also tripped. As per PMU, B-N fault occurred and delayed clearance of 280ms with no auto-reclosing observed. B-N fault. As per PMU, B-N fault occurred and delayed 03-Jul-21 05:01 clearance of 440ms with no auto-reclosing observed. B-N fault. As per PMU, B-N fault occured, no auto-reclosing 14-Jul-21 15:55 observed. B-N fault, Dist. 63.8km, Fault current 1.18kA from 7 220 KV Saharanpur(PG)-Shamli(UP) (UP) Ckt-1 Saharanpur(PG). As per PMU, B-N fault occurred and 20-Jul-21 08:04 delayed clearance of 440ms with no auto-reclosing observed. Y-N fault, FD:52.2 Km FC:3.13 KA FROM SAHARANPUR END. 29-Jul-21 07:02 As per PMU, Y-N fault occurred and delayed clearance of 440ms with no auto-reclosing observed. Outage Preliminary Report receipt status DR/EL receipt status Detailed Report receipt status Fault Name of Elements Event Generation Category as per Energy Unserved (in S.No. Region Affected Area Owner/ Agency Load Loss(MW) Clearance (Tripped/Manually opened) (As reported) Loss(MW) CEA Grid Standards MU) time (in ms) Date Time within 24hrs after 24hrs Not Received within 24hrs after 24hrs Not Received Received Not Received As reported, 800 KV HVDC Kurukshetra(PG) Pole 1 & Pole 3 blocked due to DC line fault, Category D protection operated. As 1) 800 KV HVDC Kurukshetra(PG)-Champa(PG) (PG) Ckt-1 1 NR HARYANA POWERGRID 2-Jul-21 14:48 per PMU, no fault is observed and flacutuation in voltage is observed. In antecedent condition, 800 KV HVDC Kurukshetra(PG) 0 0 GI-2 0 Y(PG) Y(PG) Y(PG) NA 2) 800kV Kurukshetra(PG)-Champa(PG) ckt-3 Pole 1 & Pole 3 carrying total 1500MW. As reported, 220 KV Tanakpur(NH)-Sitarganj(PG) (PG) Ckt-1 tripped on R-N phase to earth fault, 220 KV Sitarganj(PG)- 1) 220 KV Tanakpur(NH)-Sitarganj(PG) (PG) Ckt-1 CBGanj(UP) (PG) Ckt-1 tripped on Y-N phase to earth faut, 220 KV Tanakpur(NH)-CBGanj(UP) (PG) Ckt-1 tripped on R-Y phase 2) 220 KV Sitarganj(PG)-CBGanj(UP) (PG) Ckt-1 to phase fault, Zone-2, distance was 118.5km from CBGanj(UP) and 132 KV Mahendra Nagar(PG)-Tanakpur(NH) (PG) Ckt-1 also 3) 220 KV Tanakpur(NH)-CBGanj(UP) (PG) Ckt-1 tripped. All the lines tripped from remote end only. At the same time, 31.4 MW Tanakpur HPS - UNIT 1, UNIT 2 & UNIT 3 all Y(UP) Y(UP) Y(NHPC) 2 NR 4) 31.42 MW Tanakpur HPS - UNIT 1 UTTRAKHAND NHPC, POWERGRID 2-Jul-21 20:21 tripped on over frequency protection operation. As per PMU, R-N phase to earth fault followed by Y-N phase to earth fault 98 0 GD-1 0.25 Y(NHPC) Y(NHPC) Y(UP) 760 Y(PG) Y(PG) Y(PG) 5) 31.4 MW Tanakpur HPS - UNIT 3 with delayed clearance in 760ms is observed. As per SCADA, generation loss of approx. 98MW is observed at Tanakpur(NH). In 6) 31.4 MW Tanakpur HPS - UNIT 2 antecedent condition, 220 KV Tanakpur(NH)-Sitarganj(PG) (PG) Ckt-1, 220 KV Sitarganj(PG)-CBGanj(UP) (PG) Ckt-1, 220 KV 7) 132 KV Mahendra Nagar(PG)-Tanakpur(NH) (PG) Ckt-1 Tanakpur(NH)-CBGanj(UP) (PG) Ckt-1 & 132 KV Mahendra Nagar(PG)-Tanakpur(NH) (PG) Ckt-1 carrying 39MW, 29MW, 12MW & 70MW respectively. As reported, 220 KV Nallagarh(PG)-HPSEB(HP) (HPSEB) Ckt-2 tripped on R-N phase to earth fault. Fault occurred due to flashover in R-ph LA of 220 KV Nallagarh(PG)-HPSEB(HP) (HPSEB) Ckt-2 at Nallagarh(PG) end, fault distance was 35 meter & 1) 220 KV Nallagarh(PG)-HPSEB(HP) (HPSEB) Ckt-1 fault current was 22kA from Nallagarh(PG) end. At the same time, 220 KV Nallagarh(PG)-HPSEB(HP) (HPSEB) Ckt-1 also tripped 3 NR HIMACHAL PRADESH HPSEB 6-Jul-21 11:44 0 400 GD-1 0.67 Y(PG) Y(PG) Y(PG) Y(UP) 120 2) 220 KV Nallagarh(PG)-HPSEB(HP) (HPSEB) Ckt-2 on DT received at Nallagarh end. As per PMU, R-N phase to earth fault is observed. As per SCADA, load loss of approx. 400MW is observed in HP control area. In antecedent condition, 220 KV Nallagarh(PG)-HPSEB(HP) (HPSEB) Ckt-1 & Ckt-2 were carrying 212MW & 219MW respectively. As reported, 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-2 tripped on B-ph differential. Fault current was 3.4kA & fault distance was 11.72km from Narela end. At the same time, 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-1 also tripped from Mandola end only in Z-2 on R-N fault. As per PMU, R-B phase to phase fault is observed at 14:22:50:440 followed by R-N phase 1) 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-1 Y(PG) 4 NR NEW DELHI DTL 6-Jul-21 14:22 to earth fault at 14:23:53:480. As per SCADA SOE & PMU it seems that, 1st 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-2 tripped 0 280 GD-1 0.61 Y(PG) Y(DTL) Y(DTL) Y(PG) 120 2) 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-2 Y(DTL) on R-B fault then after approx. 1min 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-1 tripped on R-N fault. As per SCADA, load loss of approx. 280MW is observed. In antecedent condition, 220 KV Mandola(PG)-Narela(DV) (DTL) Ckt-1 & Ckt-2 were carrying approx. 178MW each. As reported, 220 KV Singoli Bhatwari (Singoli (LTUHP))-Srinagar(UK) (PTCUL) Ckt-1 & Ckt-2 both tripped on uner voltage (Y and B phase) stage-2 protection operated. Y-ph & B-ph voltages were in the range of 95kV & 93k respectively. As per PMU, no 1) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-1 fault is observed. As per SCADA, in antecedent condition bus voltages of Singoli Bhatwari were in the range of 220-222kV and Y(SINGOLI) Y(SINGOLI) Y(SINGOLI) 5 NR UTTRAKHAND PTCUL 8-Jul-21 15:36 100 0 GD-1 0.08 NA 2) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-2 generation loss of approx. 100MW is observed on tripping of 33MW three units of Singoli Bhatwari due to tripping of both Y(Utt) Y(Utt) Y(Utt) evacuting lines. In antecedent condition, 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-1 & Ckt-2 were carrying 52MW each. As reported, at 20:49 Hrs 765 KV Meerut-Bhiwani (PG) Ckt-1 tripped on R-N fault, fault current was 10.192kA & distance was 45.69km from Meerut end and fault current 5.3kA & distance was 128.24km from Bhiwani end. At 20:50 hrs, 400 KV Meerut- Baghpat (PG) Ckt-2 tripped on R-B fault, fault currents was Ir 14.2kA, Ib 20kA & distance was 12km from Baghpat end and fault 1) 765 KV Meerut-Bhiwani (PG) Ckt-1 currents were Ir 9.61kA, Ib 9.68kA & distance was 44.1km from Meerut end. At 20:51 Hrs, 00 KV Baghpat-Kaithal (PG) Ckt-1 & 2) 400 KV Meerut-Baghpat (PG) Ckt-2 6 NR UTTAR PRADESH POWERGRID 8-Jul-21 20:49 Ckt-2 tripped on R-N & Y-N fault respectively during bad weather consition which also led to tower collapsed. As per PMU, at 0 150 GD-1 0.18 Y(PG) Y(PG) Y(PG) 80 3) 400 KV Baghpat-Kaithal (PG) Ckt-1 20:49 Hrs R-N phase to earth fault with unsuccessful autorecloser is observed, at 20:50 hrs R-B phase to phase fault is 4) 400 KV Baghpat-Kaithal (PG) Ckt-2 observed with fault current in the range of 5kA and at 20:51hrs R-N & Y-N faults are observed. As per SCADA, load loss of approx. 150MW is observed in UP control area. In antecedent condition, 765 KV Meerut-Bhiwani (PG) Ckt-1, 400 KV Meerut- Baghpat (PG) Ckt-2, 400 KV Baghpat-Kaithal (PG) Ckt-1 & Ckt-2 were carrying 205MW, 121MW, 52MW & 51MW respectively. As reported, while change over of load from Bus D to Bus B while availing shutdown of 220kV Pappankalan-II Ckt-I, 220kV side Y Phase Bushing clamp along with bushing oil monitoring glass of 400/220kV 315MVA ICT-1 got blast, which resulted into 1) 400/220 kV 315 MVA ICT 4 at Bamnoli(DV) tripping of 400/220kV 315MVA ICT-1, 400/220kV 500MVA ICT 2, 400/220kV 500MVA ICT 3 & 400/220kV 315MVA ICT 4 at 2) 400/220 kV 500 MVA ICT 2 at Bamnoli(DV) 7 NR NEW DELHI DTL 9-Jul-21 10:24 Bamnoli(DV) and all 220kV lines. As per PMU, RYB three phase fault is observed with delayed clearance in 2600ms. As per 0 950 GD-1 0.33 Y(DTL) Y(DTL) Y(DTL) 2600 3) 400/220 kV 315 MVA ICT 1 at Bamnoli(DV) SCADA, load loss of approx. 950MW is observed. As per SOE, 220kV Bamnauli-DIAL-1 & 2 tripped before tripping of ICTs. In 4) 400/220 kV 500 MVA ICT 3 at Bamnoli(DV) antecedent condition, 400/220kV 315MVA ICT-1, 400/220kV 500MVA ICT 2, 400/220kV 500MVA ICT 3 & 400/220kV 315MVA ICT 4 at Bamnoli(DV) were carrying 150MW, 221MW, 220MW & 154MW respectively. As reported, 400/220 kV 315 MVA ICT 1 at Mundka(DV) tripped at 21:56Hrs on mal-operation of buchloz relay operation 1) 400/220 kV 315 MVA ICT 1 at Mundka(DV) probably due to starting of both side oil pumps. At 21:59 Hrs, 400/220 kV 315 MVA ICT 3 & ICT 4 both tripped on back up over 8 NR 2) 400/220 kV 315 MVA ICT 3 at Mundka(DV) NEW DELHI DTL 9-Jul-21 21:56 current protection operation at 220kV side. Due to tripping of ICTs, load of Peeragarhi, Wazirpur and part load of Najafagarh 0 600 GD-1 0.34 Y(DTL) Y(DTL) Y(DTL) NA 3) 400/220 kV 315 MVA ICT 4 at Mundka(DV) affected. As per PMU, no fault is observed. As per SCADA, load loss of approx. 600MW is observed in Delhi control area. In antecedent condition, MW loading of 315 MVA ICT 1, ICT 2 & ICT 3 221MW, 336MW & 326MW respectively. As reported, 400 KV Jodhpur-Kankani (RS) Ckt-2 tripped from Jodhpur end only. At the same time, 400 KV Bhadla-Jodhpur 1) 400 KV Bhadla-Jodhpur (RS) Ckt-1 (RS) Ckt-1 also tripped on B-N fault in Z-1 from Jodhpur end with distance of 4.8km & fault current of 11.05kA. As per PMU, Y- 9 NR RAJASTHAN RRVPNL 10-Jul-21 23:59 0 0 GI-2 0 Y(Raj) Y(Raj) Y(Raj) 440 2) 400 KV Jodhpur-Kankani (RS) Ckt-2 N phase to earth fault is observed with delayed clearance in 440ms. In antecedent condition, 400 KV Bhadla-Jodhpur (RS) Ckt- 1 & 400 KV Jodhpur-Kankani (RS) Ckt-2 were carrying 94MW & 4MW respectively. As reported, 800 KV HVDC Agra(PG) Pole-1 & Pole-3 blocked on DC line differential protection operation. As per PMU, no fault 1) 800 KV HVDC Agra(PG) Pole-1 10 NR UTTAR PRADESH POWERGRID 11-Jul-21 07:00 is observed & fluctuation in voltage is observed. In antecedent condition, 800 KV HVDC Agra(PG) Pole-1 & Pole-3 were 0 0 GI-2 0 Y(PG) Y(PG) Y(PG) NA 2) 800 KV HVDC Agra(PG) Pole-3 carrying total 1600MW. As reported, 220 KV Khodri(UK)-Majri(HP) (UK) Ckt-1 tripped on R-N phase to earth fault. Fault was in Z-1 from both end, fault distance was 10.79km & fault current was 2.28kA from Majri(HP) end. At the same time, 220 KV Khodri(UK)-Majri(HP) (UK) Ckt- 1) 220 KV Khodri(UK)-Majri(HP) (UK) Ckt-1 11 NR UTTRAKHAND PTCUL 11-Jul-21 13:32 2 also tripped from Khodri(UK) end only. As per PMU, B-N phase to earth fault with delayed clearance in 520ms is observed. 0 80 GD-1 0.09 Y(HP) Y(Utt) Y(HP) Y(Utt) Y(HP) Y(Utt) 520 2) 220 KV Khodri(UK)-Majri(HP) (UK) Ckt-2 As per SCADA, load loss of approx. 80MW is observed. In antecedent condition, 220 KV Khodri(UK)-Majri(HP) (UK) Ckt-1 & Ckt- 2 were carrying 42MW & 40MW respectively. 1) 220KV Bus 2 at Samaypur(BB) 2) 220KV Bus 1 at Samaypur(BB) 3) 220 KV Ballabhgarh(BB)-Badarpur(NT) (BB) Ckt-1 As reported, there was a heavy spark between male & female fingers of Bus-1 220kV Samaypur red phase isolator of 4) 220 KV Ballabhgarh-Samaypur (BB) Ckt-2 400/220kV 500MVA ICT-2 at Badshahpur(PG). 400/220kV 500MVA ICT-2 at Badshahpur(PG) tripped on backup impedance 5) 220 KV Faridabad(NT)-Samaypur(BB) (PG) Ckt-2 protection operation as bus bar protection of Samaypur S/s was out of service since 10/06/21 for the recommissioning of the 6) 220 KV Faridabad(NT)-Samaypur(BB) (PG) Ckt-1 new central unit. At the same time, 400/220kV 500MVA ICT-1, ICT-3 & ICT-4 at Badshahpur(PG) also tripped on backup Y(BBMB) Y(BBMB) Y(BBMB) 12 NR HARYANA BBMB, POWERGRID 13-Jul-21 04:58 0 650 GD-1 1.73 Y(DTL) Y(PG) Y(DTL) Y(PG) Y(PG) 560 7) 220 KV Ballabhgarh-Samaypur (BB) Ckt-3 impedance protection operation. 220kV lines to Faridabad, Badarpur & Ballabhgarh also tripped in Z-4. As per PMU, B-N phase Y(NTPC) Y(NTPC) Y(NTPC) 8) 220 KV Ballabhgarh-Samaypur (BB) Ckt-1 to earth fault with delayed clearance in 560ms is observed. As per SCADA, load loss of approx. 650MW is observed in Haryana 9) 400/220 kV 500 MVA ICT 2 at Ballabhgarh(PG) control area. In antecedent condition, 400/220kV 500MVA ICT-1, ICT-2, ICT-3 & ICT-4 at Badshahpur(PG) were carrying approx. 10) 400/220 kV 500 MVA ICT 1 at Ballabhgarh(PG) 185MW. 11) 400/220 kV 500 MVA ICT 3 at Ballabhgarh(PG) 12) 400/220 kV 500 MVA ICT 4 at Ballabhgarh(PG) As reported, R-N phase to earth fault occurred in 132kV Gladni switchyard of JKPTCL. Fault current was 1.9kA from Jammu end. Fault occurred due to monkeys climbing on 200/132kV Transformer in Gladni switchyard. During this fault 220 KV Salal(NH)-Jammu(PDD) (PG) Ckt-1, Ckt-2 and 220 KV Samba(PG)-Jammu(PDD) (PG) Ckt-1 tripped on directional earth fault 1) 220 KV Samba(PG)-Jammu(PDD) (PG) Ckt-1 protection operation at Salal & Samba end. As per PMU, R-N phase to earth fault with delayed clearance in 1980ms is Y(PG) Y(PG) 13 NR 2) 220 KV Salal(NH)-Jammu(PDD) (PG) Ckt-2 J & K POWERGRID 14-Jul-21 07:06 observed. Fault was in 132kV switchyard of Gladni and as fault didn't clear from Gladni end, firstly 220 KV Salal(NH)- 0 220 GD-1 0.43 Y(JK) Y(JK) Y(NHPC) Y(JK) 1960 Y(NHPC) Y(NHPC) 3) 220 KV Salal(NH)-Jammu(PDD) (PG) Ckt-1 Jammu(PDD) (PG) Ckt-1 & Ckt-2 tripped but still fault was feded by Samba line. Finally fault cleared after tripping of 220kV Samba-Jammu line from Samba end. As per SCADA, load loss of approx. 220MW is observed in J&K (UT) control area. In antecedent condition, 220 KV Salal(NH)-Jammu(PDD) (PG) Ckt-1, Ckt-2 and 220 KV Samba(PG)-Jammu(PDD) (PG) Ckt-1 were carrying 132MW, 118MW & 42MW respectively. Outage Preliminary Report receipt status DR/EL receipt status Detailed Report receipt status Fault Name of Elements Event Generation Category as per Energy Unserved (in S.No. Region Affected Area Owner/ Agency Load Loss(MW) Clearance (Tripped/Manually opened) (As reported) Loss(MW) CEA Grid Standards MU) time (in ms) Date Time within 24hrs after 24hrs Not Received within 24hrs after 24hrs Not Received Received Not Received As reported, 400KV Bus 1 at Muradnagar_2(UP), 400 KV Muradnagar_2-Mathura (UP) Ckt-1 & 400KV Dadri(NT)- 1) 400 KV Muradnagar_2-Mathura (UP) Ckt-1 Muradnagar_2(UP) (PG) Ckt-1 all tripped during Y-N fault. Fault current was 3.6kA & fault distance was 67.2km from 14 NR 2) 400KV Bus 1 at Muradnagar_2(UP) UTTAR PRADESH POWERGRID, UPPTCL 17-Jul-21 04:08 Mathura(UP) end. As per PMU, Y-N phase to earth fault with delayed clearance in 320ms is observed. In antecedent condition, 0 0 GI-2 0 Y(UP) Y(UP) Y(UP) 320 3) 400KV Dadri(NT)-Muradnagar_2(UP) (PG) Ckt-1 400 KV Muradnagar_2-Mathura (UP) Ckt-1 & 400KV Dadri(NT)-Muradnagar_2(UP) (PG) Ckt-1 carrying 39MW & 250MW respectively. As reported, at 11:30Hrs 400/220kV 315MVA ICT-1 tripped on Buccholz Relay operation. At the same time, 400/220kV 1) 400/220 kV 315 MVA ICT 1 at Mundka(DV) 315MVA ICT-3 tripped on overloading. As per PMU, no fault is observed. As per SCADA, load loss of approx. 450MW is 15 NR NEW DELHI DTL 17-Jul-21 11:31 0 450 GD-1 0.06 Y(DTL) Y(DTL) Y(DTL) NA 2) 400/220 kV 315 MVA ICT 3 at Mundka(DV) observed in Delhi control area. In antecdent condition, 400/220kV 315MVA ICT-1 & ICT-3 at Mundka(DV) were carrying 218MW & 223MW respectively. As reported, R-B phase to phase fault occurred due to heavy spark in R-ph bus-1 isolator of 220 KV Fatehabad(PG)- Fatehabad(HV) (HVPNL) Ckt-1 and in blue phase bus connecting jumper of bus-1 is observed. Fault was in Z-2 of 1) 220 KV Fatehabad(PG)-Fatehabad(HV) (HVPNL) Ckt-1 Fatehabad(PG) end. During this event, 220 KV Hissar(PG)-Fatehabad(HV) (HVPNL) Ckt-1 & Ckt-2 tripped in Z-4 from 2) 220 KV Fatehabad(PG)-Fatehabad(HV) (HVPNL) Ckt-2 Fatehabad(HV) end. At the same time, 220 KV Fatehabad(PG)-Fatehabad(HV) (HVPNL) Ckt-1 & Ckt-2 tripped from Y(PG) Y(PG) 16 NR HARYANA HVPNL 19-Jul-21 04:15 0 360 GD-1 1.62 Y(Har) Y(PG) 400 3) 220 KV Hissar(PG)-Fatehabad(HV) (HVPNL) Ckt-2 Fatehabad(PG) end only in Z-2 (7km). As per PMU, R-B phase to phase fault is observed with delayed clearance in 400ms. From Y(Har) Y(Har) 4) 220 KV Hissar(PG)-Fatehabad(HV) (HVPNL) Ckt-1 PMU & SOE it seems that 220 KV Fatehabad(PG)-Fatehabad(HV) (HVPNL) Ckt-1 & Ckt-2 didn't trip from Fatehabad(HV) end in Z-4 which led to delayed clearance of fault in Z-2 from Fatehabad(PG) end. As per SCADA, load loss of approx. 360MW is observed in Haryana control area. 1) 220 KV Bhiwani-Hissar (BB) Ckt-1 2) 220 KV Bhiwani-Charkhi Dadri (BB) Ckt-3 As reported, 220 KV Bhiwani-Hissar (BB) Ckt-1, 220 KV Bhiwani-Charkhi Dadri (BB) Ckt-1 & Ckt-3, 220 KV Bhiwani(HV)- 3) 220 KV Bhiwani(HV)-Bhiwani(BB) (HVPNL) Ckt-1 Bhiwani(BB) (HVPNL) Ckt-1 & 400/220 kV 500 MVA ICT 1 at Bhiwani(BB) all tripped on Bus bar protection operation of Bus-1. Y(BBMB) Y(BBMB) 17 NR HARYANA BBMB, HVPNL 19-Jul-21 14:14 0 0 GI-2 0 Y(BBMB) NA 4) 220KV Bus 1 at Bhiwani(BB) Bus bar operated due to damage of bus bar-1 isolator status selector cable. As per PMU, no fault is observed. In antecedent Y(Har) Y(Har) 5) 400/220 kV 500 MVA ICT 1 at Bhiwani(BB) condition, 400/220 kV 500 MVA ICT 1 at Bhiwani(BB) carrying 230MW. 6) 220 KV Bhiwani-Charkhi Dadri (BB) Ckt-1 As reported, 220 KV Akal-Dangri Ckt-1 & Ckt-2 tripped from Akal end on R-Y phase to phase fault.Fault distance was 1) 220kV Akal–Dangri (RS) ckt-1 174.8meter and fault currents were Ir=17.49kA & Iy=18.14kA from Akal end. At the same time, 220kV Akal-Bhu Ckt-1 & Ckt-2 2) 220kV Akal–Dangri (RS) ckt-2 and 220kV Akal-Jajia ckt also tripped from remote end only. As per PMU, R-Y phase to phase fault is observed which cleared 18 NR 3) 220kV Akal–Bhu (RS) ckt-1 RAJASTHAN RRVPNL 20-Jul-21 10:25 1550 0 GD-1 2.58 Y(Raj) Y(Raj) Y(Raj) Y(UP) 80 within 100ms. As per SCADA, wind generation loss of approximately 1550MW is observed. In antecedent condition, 220 KV 4) 220kV Akal–Bhu (RS) ckt-2 Akal-Dangri Ckt-1 & Ckt-2, 220kV Akal-Bhu Ckt-1 & Ckt-2 and 220kV Akal-Jajia ckt carrying 165MW, 48MW, 155MW, 168MW & 5) 220kV Akal-Jajiya (RS) Ckt 176MW respectively. 1) 82.5 MW Alakhanda HEP - UNIT 1 2) 110 MW Vishnuparyag HPS - UNIT 4 3) 110 MW Vishnuparyag HPS - UNIT 1 As reported, 400kV Alaknanda-Muzaffarnagar Ckt tripped on Y-N phase to earth fault. Fault was in Z-1 from both end, fault 4) 400 KV Alaknanda GVK(UPC)-Vishnuprayag(JP) (UP) Ckt-1 current was 2.3kA and distance was 81.89km from Alaknanda end & 111.49km from Muzaffarnagar end,. Due to tripping of 5) 400 KV Alaknanda GVK(UPC)-Muzaffarnagar (UP) Ckt-1 above line, Alaknanda generation was evacuating from Vishnuprayag - Muzaffarnagar line which resulted into tripping of 6) 82.5 MW Alakhanda HEP - UNIT 4 400KV Muzaffarnagar(UP)-Vishnuprayag(JP) (UP) Ckt on over current protection operation at Vishnuprayag end. At the same 7) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-2 time, 400 KV Alaknanda GVK(UPC)-Vishnuprayag(JP) (UP) Ckt-1, 400kV Alaknanda-Srinagar ckt-1 & Ckt-2 also tripped. Due to Y(SINGOLI) UTTAR PRADESH ; Y(SINGOLI) Y(SINGOLI) 19 NR 8) 110 MW Vishnuparyag HPS - UNIT 3 UPPTCL 20-Jul-21 14:39 tripping of all evacuating lines all the units of Alaknanda HEP, Vishnuprayag HEP & Singoli Bhatwari HEP tripped on over speed 890 70 GD-1 0.35 Y(UP) Y(Utt) Y(UP) 80 UTTRAKHAND Y(Utt) Y(Utt) 9) 110 MW Vishnuparyag HPS - UNIT 2 protection operation. As per PMU, Y-N phase to earth fault is observed followed by oscillations for about 10 secs. As per Y(UP) 10) 82.5 MW Alakhanda HEP - UNIT 3, 82.5 MW Alakhanda HEP - UNIT 2 SCADA, load loss of approx. 70MW is observed in Uttarakhand control area and hydro generation loss of approx. 345MW, 11) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-1 440MW & 107MW of Alaknanda HEP, Vishnuprayag HEP & Singoli Bhatwari HEP due to tripping of all units. In antecedent 12) 400KV Muzaffarnagar(UP)-Vishnuprayag(JP) (UP) Ckt-1 condition, 400kV Alaknanda-Muzaffarnagar Ckt, 400kV Alaknanda-Vishnuprayag Ckt & 400kV Vishnuprayag-Muzaffarnagar Ckt 13) 33MW Singoli Bhatwari UNIT 1 were carrying 452MW, 86MW & 349MW respectively. 14) 33MW Singoli Bhatwari UNIT 2 15) 33MW Singoli Bhatwari UNIT 3 As reported, 220 KV Wagoora(PG)-Pampore(PDD) (PG) Ckt-1 & Ckt-2 tripped from Pampore end only on overcurrent 1) 220 KV Wagoora(PG)-Pampore(PDD) (PG) Ckt-1 protection operation at Pampore end on B-N phase to earth fault. At the same time, 220kV Pampore-Mirbazar (PDD JK) Ckt-1 2) 220 KV Wagoora(PG)-Pampore(PDD) (PG) Ckt-2 Y(PG) 20 NR J & K PDD JK 22-Jul-21 16:20 & Ckt-2 also tripped along with multiple element tripping at 132kV Mirbazar. As per PMU, R-N phase to earth fault with 0 500 GD-1 0.73 Y(JK) Y(JK) 480 3) 220kV Pampore-Mirbazar (PDD JK) Ckt-1 Y(JK) delayed clearance in 480ms is observed. As per SCADA, load loss of approx. 500MW is observed in J&K control area. In 4) 220kV Pampore-Mirbazar (PDD JK) Ckt-2 antecedent condition, 220 KV Wagoora(PG)-Pampore(PDD) (PG) Ckt-1 & Ckt-2 carrying 207MW & 217MW respectively. 1) 400/220 kV 315 MVA ICT 1 at Bikaner(RS) As reported, 400/220 kV 315 MVA ICT 1 & ICT 2 at Bikaner(RS) both tripped on Y-ph over current earth fault protection 21 NR RAJASTHAN RRVPNL 22-Jul-21 17:08 0 0 GI-2 0 Y(Raj) Y(Raj) Y(Raj) 0 2) 400/220 kV 315 MVA ICT 2 at Bikaner(RS) operation. As per PMU, no fault is observed. 1) 400/220 kV 315 MVA ICT 1 at Bareilly(UP) As reported, flash over was observed in 400/220 kV 315 MVA ICT 3 at Bareilly(UP) which tripped on directional earth fault 2) 220 KV Pithoragarh(PG)-Bareilly(UP) (PG) Ckt-1 protection operation. As fault didn't clear, 400/220 kV 315 MVA ICT 1 & ICT-2 at Bareilly(UP) both tripped on over current 3) 220 KV Dhauliganga(NH)-Pithoragarh(PG) (PG) Ckt-1 protection operation. At the same time, 220kV lines to CB Ganj, Dohna, Pilibhit, Dhauliganga & Pithoragarh also tripped. Due Y(UP) 22 NR 4) 220 KV Dhauliganga(NH)-Bareilly(UP) (PG) Ckt-1 UTTAR PRADESH POWERGRID, UPPTCL 23-Jul-21 16:36 to tripping of evacuating lines all units of Dhauliganga also tripped. As per PMU, R-B phase to phase fault is observed with 280 300 GD-1 0.58 Y(NHPC) Y(Utt) Y(NHPC) Y(UP) Y(NHPC) Y(UP) 2840 5) 400/220 kV 315 MVA ICT 3 at Bareilly(UP) delayed clearance in 2840ms. As per SCADA, load loss of approx. 300MW in UP control area & generation loss of 280MW is Y(PG) Y(PG) Y(PG) 6) 400/220 kV 315 MVA ICT 2 at Bareilly(UP) observed at Dhauliganga HEP. In antecedent condition, 400/220 kV 315 MVA ICT 1, ICT-2 & ICT 3 at Bareilly(UP) were carrying 7) 220 KV Pantnagar(UK)-Bareilly(UP) (UP) Ckt-1 approx. 99MW each. 1) 400/220 kV 315 MVA ICT 1 at Gr.Noida(UPC) As reported, OPGW of 220kV Gr.Noida-Noida sec 20 ckt-2 snapped and fell on Y-ph which created Y-N fault. Y-ph got open on 2) 400/220 kV 500 MVA ICT 5 at Gr.Noida(UPC) distance protection operation. Simultaneously, B-ph also came in contact with snapped OPGW but line didn't trip. Due to this, 3) 220kV Gr.Noida-Noida sec 20 ckt-1 B-ph isolator of 220kV Gr.Noida-Noida sec 20 ckt-2 damaged and created bus fault which resulted into bus bar protection 23 NR 4) 220kV Gr.Noida-Noida sec 20 ckt-2 UTTAR PRADESH UPPTCL 23-Jul-21 16:38 operation and all 220kV lines connected to Bus-1, 400/220 kV 315 MVA ICT 1 and 400/220 kV 500 MVA ICT 5 at Gr.Noida(UPC) 0 350 GD-1 1.02 Y(UP) Y(UP) Y(UP) 1200 5) 220kV Gr.Noida-RC Green ckt-1 tripped. As per PMU, Y-N phase to earth fault followed by B-N which later converted into R-B fault with delayed clearance in 6) 220kV Gr.Noida-RC Green ckt-2 1200ms is observed. As per SCADA, load loss of approx. 350MW is observed in UP control area. In antecedent condition, 7) 220kV Gr.Noida-RC Green ckt-3 400/220 kV 315 MVA ICT 1 and 400/220 kV 500 MVA ICT 5 were carrying 134MW & 221MW respectively. As reported, 220 KV AD hydro(AD)-Nallagarh(PG) (ADHPL) Ckt-1 tripped on Y-B phase to phase fault. Fault distance was 1) 220 KV AD hydro(AD)-Nallagarh(PG) (ADHPL) Ckt-1 133km from Nallagarh and 44.9km (Z-1) from AD Hydro end. At the same time, 220 KV AD hydro(AD)-Phozal(HP) (ADHPL) Ckt- Y(AD Hydro) Y(AD Hydro) Y(AD Hydro) 2) 220 KV Phozal(HP)-Nallagarh(PG) (ADHPL) Ckt-1 1 & 220 KV Phozal(HP)-Nallagarh(PG) (ADHPL) Ckt-1 tripped on over voltage followed by tripping of 96MW AD Hydro Unit 1 & 24 NR UTTRAKHAND ADHPL 28-Jul-21 05:03 230 0 GD-1 0.1 Y(HP) Y(HP) Y(HP) 80 3) 220 KV AD hydro(AD)-Phozal(HP) (ADHPL) Ckt-1 Unit 2 as no evacuation path was available. As per PMU, Y-B phase to phase fault is observed. As per SCADA, generation loss of Y(PG) Y(PG) Y(PG) 4) 96 MW AD hydro - UNIT 1, 96 MW AD hydro - UNIT 2 approx. 230MW is observed at of AD Hydro HEP. In antecedent condition, 220kV AD Hydro- Nallagarh Ckt, 220kV AD Hydro - Phozal ckt and 220kV AD Hydro - Nallagarh Ckt were carrying 139MW, 89MW & 135MW respectively. 1) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-1 As reported, 220 KV Singoli Bhatwari-Srinagar Ckt-1 tripped on Y-N phase to phase fault. At the same time, 220 KV Singoli 2) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-2 Bhatwari-Srinagar Ckt-2 also tripped on DT received from Srinagar(UK) end. As per PMU, Y-B phase to phase fault is observed. Y(SINGOLI) Y(SINGOLI) Y(SINGOLI) 25 NR 3) 33MW Singoli Bhatwari UNIT 1 UTTRAKHAND PTCUL 28-Jul-21 14:38 98 90 GD-1 0.2 80 As per SCADA, load loss of approx. 90MW & generation loss of approx. 98MW at Singoli Bhatwari HEP observed. In antecedent Y(Utt) Y(Utt) Y(Utt) 4) 33MW Singoli Bhatwari UNIT 2 condition, 220kV Singoli Bhatwari-Srinagar Ckt-1 & Ckt-2 were carrying 49MW each. 5) 33MW Singoli Bhatwari UNIT 3 As reported, Tie CB of unit 1 and 400 kV Alaknanda-Srinagar ckt 1 at Alaknanda end blasted following which 400 KV Alaknanda 1) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-1 GVK(UPC)-Srinagar(UK) (UK) Ckt-1 tripped and DT received at Srinagar end. At the same time, 220 KV Singoli Bhatwari-Srinagar 2) 220 KV Singoli Bhatwari(Singoli(LTUHP))-Srinagar(UK) (PTCUL) Ckt-2 Ckt-2 also tripped on under voltage protection operation folowed by tripping of 220kV Singoli Bhatwari - Srinagar Ckt-1. With Y(SINGOLI) Y(SINGOLI) Y(SINGOLI) 3) 400 KV Alaknanda GVK(UPC)-Srinagar(UK) (UK) Ckt-1 26 NR UTTRAKHAND PTCUL 29-Jul-21 16:31 tripping of both lines at Singoli Bhatwari, all three units tripped on loss of evacuation path. As per PMU, no fault is observed. 197 0 GD-1 0.11 Y(Utt) Y(Utt) Y(Utt) NA 4) 33MW Singoli Bhatwari UNIT 1 As per SCADA, generation loss of approx. 107MW at Singoli Bhatwari & 90MW at Alaknanda HEP observed. In antecedent Y(UP) Y(UP) Y(UP) 5) 33MW Singoli Bhatwari UNIT 2 condition, 220kV Singoli Bhatwari - Srinagar Ckt-1 & Ckt-2, 220kV Alaknanda-Srinagar Ckt-1 were carrying 54MW, 54MW & 6) 33MW Singoli Bhatwari UNIT 3 49MW respectively. Northern Regional inter regional lines tripping for June-21 # Fault Outage Restoration Other Protection Clearance Load Category as DR/EL Issues and Non Time *FIR Loss/ Brief Reason per CEA provided Compliance Suggestive Remedial S. No. Name of Transmission Element Tripped Owner/ Utility (>100 ms for Furnished Remarks Gen. (As reported) Grid in 24 hrs (inference from Measures 400 kV and (YES/NO) Date Time Loss standards Date Time (YES/NO) PMU, utility 160 ms for details) 220 kV) 800 KV HVDC Kurukshetra(PG)- From PMU, No AC system fault 1 POWERLINK 2-Jul-21 14:48 Nil Tripped on DC line fault. NA 2-Jul-21 17:14 NA Yes Yes Champa(PG) (PG) Pole-1 observed. 800 KV HVDC Kurukshetra(PG)- Yes(After Yes(After From PMU, No AC system fault 2 POWERLINK 2-Jul-21 14:48 Nil Tripped on DC line fault. NA 2-Jul-21 17:49 NA Champa(PG) (PG) Pole-3 24Hrs) 24Hrs) observed. Due to heavy lightening and rain, Pole-3 got blocked due to Failure of From PMU, No AC system fault 3 800 KV HVDC Kurukshetra(PG) Pole-3 POWERGRID 4-Jul-21 17:05 Nil NA 4-Jul-21 19:50 NA Yes Yes Auxiliary changeover at Champa observed. end. External block protection operated due to low SF6 level alarm in Voltage divider. However, The actual level of SF6 is within the limits and Yes(After Yes(After From PMU, No AC system fault 4 800 KV HVDC Kurukshetra(PG) Pole-2 POWERGRID 15-Jul-21 16:48 Nil reason for protection is mal- NA 15-Jul-21 18:08 NA 24Hrs) 24Hrs) observed. operation of SF6 level sensor contacts due to moisture ingress resulting from heavy rain in the region. # Fault Clearance time has been computed using PMU Data from nearest node available and/or DR provided by respective utilities ( Annexure- II) *Yes, if written Preliminary report furnished by constituent(s) R-Y-B phase sequencing (Red, Yellow, Blue) is used in the list content.All information is as per Northern Region unless specified. ^^ tripping seems to be in order as per PMU data, reported information. However, further details may be awaited. Reporting of Violation of Regulation for various issues for above tripping Fault Clearance time(>100ms for 400kV 1 1. CEA Grid Standard-3.e 2. CEA Transmission Planning Criteria and >160ms for 220kV) 2 DR/EL Not provided in 24hrs 1. IEGC 5.2(r) 2. CEA Grid Standard 15.3 3 FIR Not Furnished 1. IEGC 5.9.6.a 2. CEA Grid Standard 12.2 (Applicable for SLDC, ALDC only) 4 Protection System Mal/Non Operation 1. CEA Technical Standard of Electrical Plants and Electric Lines: 43.4.A 2. CEA (Technical Standards for connectivity to the Grid) Regulation, 2007: Schedule Part 1. (6.1, 6.2, 6.3) 5 A/R non operation 1. CEA Technical Standard of Electrical Plants and Electric Lines: 43.4.C 2. CEA Technical Planning Criteria 1st Jul 2021 - 31st Jul 2021 Disturbance Event Disturbance Tripping First Information Disturbance Recorder Event Logger Logger Event Logger Tripping Tripping S. No. Recorder Report (NA) Report (Not Recorder (Not (NA) as (Not (NA) as (Not Report (Not Report (Not Utility (Not as informed Total No. Received) Received) informed by Received) informed Received) Received) Received) Received) by utility of tripping utility by utility Value % Value % Value % Value % 1 AD HYDRO 4 0 0 0 2 0 0 2 0 2 0 50 2 ANTA-NT 3 0 0 0 0 0 0 0 0 0 0 0 3 AURAIYA-NT 1 0 0 0 0 0 0 0 0 0 0 0 4 BBMB 44 14 32 14 20 58 16 18 62 16 4 40 5 CPCC1 67 24 36 24 8 41 24 10 42 24 6 39 6 CPCC2 32 1 3 1 3 3 1 4 4 10 0 31 7 CPCC3 45 3 7 3 6 8 3 6 8 5 3 12 8 DADRIGAS-NT 1 1 100 1 0 100 1 0 100 1 0 100 9 DADRI-NT 7 0 0 2 3 50 2 3 50 4 1 67 10 DHAULIGANGA-NH 2 0 0 0 0 0 0 0 0 0 0 0 11 FARIDABAD-NT 3 1 33 0 0 0 0 0 0 0 0 0 12 JHAJJAR 1 1 100 1 0 100 1 0 100 1 0 100 13 KOLDAM-NT 1 0 0 0 0 0 0 0 0 0 0 0 14 NAPP 3 0 0 0 0 0 0 0 0 0 0 0 15 RAPPA 3 1 33 3 0 100 3 0 100 3 0 100 16 RAPPB 1 0 0 1 0 100 1 0 100 1 0 100 17 RAPPC 3 3 100 2 0 67 2 0 67 3 0 100 18 RIHAND-NT 1 0 0 0 0 0 0 0 0 0 0 0 19 SALAL-NH 2 0 0 0 0 0 0 0 0 0 0 0 20 SEWA-2-NH 1 0 0 0 0 0 0 0 0 0 0 0 21 SINGOLI 8 8 100 8 0 100 8 0 100 8 0 100 22 SINGRAULI-NT 3 0 0 0 1 0 0 1 0 0 0 0 23 SLDC-DV 31 0 0 0 9 0 0 13 0 7 1 23 24 SLDC-HP 11 0 0 0 8 0 0 8 0 0 0 0 25 SLDC-HR 25 0 0 3 1 13 3 0 12 4 0 16 26 SLDC-JK 21 4 19 5 16 100 5 16 100 5 11 50 27 SLDC-PS 8 2 25 7 0 88 7 0 88 8 0 100 28 SLDC-RS 57 0 0 24 9 50 25 8 51 17 2 31 29 SLDC-UK 24 23 96 24 0 100 24 0 100 24 0 100 30 SLDC-UP 134 20 15 39 31 38 42 42 46 35 7 28 31 STERLITE 9 0 0 0 2 0 0 2 0 9 0 100 32 TANAKPUR-NH 7 0 0 0 0 0 0 0 0 1 0 14 33 TANDA-NT 1 0 0 0 1 0 0 1 0 0 0 0 34 TATAPOWER 1 1 100 1 0 100 1 0 100 1 0 100 35 UNCHAHAR-NT 2 0 0 0 0 0 0 0 0 0 0 0 Date of last PSS Date of last Step Report tuning / re-tuning Response Test submitted to S. No. Name of the Generatng Station (Capacity in MW) performed (in performed (in Remarks (if any) NRLDC/NRPC DD/MM/YYYY DD/MM/YYYY format (Yes/ No) format ) ) 1 THDC 07/01/2019 to 07/01/2019 to TEHRI HPS( 4 * 250 ) Yes (Report shared vide email dt.19.01.2019) 10/01/2019 10/01/2019 17/03/2019 to 17/03/2019 to KOTESHWAR HPS( 4 * 100 ) Yes (Report shared vide email dt.11.02.2021) 19/03/2019 19/03/2019 2 SJVNL NATHPA-JHAKRI HPS( Unit1 #250) 10.03.2020 - No Excitation system upgraded in 2020 The existing excitation system is very old and obsoleted forwhich support for PSS tuning is not available from OEM (Mls Voith Hydro), although NJHPS, SJVN has placed work order on 08/12/201 5. Further being the critical component, it is not possibIe”io get the PSS NATHPA-JHAKRI HPS( Unit2 #250) 14.03.2013 - No tuning done from any other vender except OEM (Mls Voith Hydro) being the system and software specific job. Therefore, prpposal for upgradation of the excitation system of this unit is under process and PSS tuning shall be carried out during upgradation of excitation system. NATHPA-JHAKRI HPS( Unit3 #250) 03.03.2020 - No Excitation system upgraded in 2020 The existing excitation system is very old and obsoleted forwhich support for PSS tuning is not available from OEM (Mls Voith Hydro), although NJHPS, SJVN has placed work order on 08/12/201 5. Further being the critical component, it is not possibIe”io get the PSS NATHPA-JHAKRI HPS( Unit4 #250) 14.03.2013 - NO tuning done from any other vender except OEM (Mls Voith Hydro) being the system and software specific job. Therefore, prpposal for upgradation of the excitation system of this unit is under process and PSS tuning shall be carried out during upgradation of excitation system. NATHPA-JHAKRI HPS( Unit5 #250) 14.05.2016 14.05.2016 NO Excitation system upgraded in 2013 NATHPA-JHAKRI HPS( Unit6 #250) 14.05.2017 14.05.2017 NO Excitation system upgraded in 2013 27.10.2020,10.02.201 PSS tuning was done at the time of commissioning of Excitation System by OEM (M/s RAMPUR HEP( 6 * 68.67 ) 29.11.2014 YES 21 BHEL). Since then response of PSS is checked regularly and found satisfactory. 3 HVPNL PANIPAT TPS( unit1# 250 ) 29.03.2016 29.03.2016 YES -- PANIPAT TPS( unit2# 250 ) 15.01.2018 15.01.2018 YES -- DCRTPP (YAMUNA NAGAR)( unit1#300 ) 19-12-2018 19-12-2018 YES (Report attached) DCRTPP (YAMUNA NAGAR)( unit1#300 ) Will be carried out shortly Report attached. No MW capacity addition after 2013 at RGTPP Khedar. RGTPP( KHEDAR) (2*600) 5th to 6th July 2013 5th to 6th July 2013 Previous record No new line addition in vicinity of station being looked into JHAJJAR(CLP) (2*660) 20-05-2017 20-05-2017 YES -- 4 NTPC Rihand ( Unit1#500 ) 03-03-2017 03-03-2017 YES Next test will be done during re-commissioning of unit after O/H Rihand ( Unit2#500 ) 02-07-2016 02-07-2016 YES Next test will be done during re-commissioning of unit after O/H Rihand ( Unit3#500 ) 15-08-2015 15-08-2015 YES Next test will be done during re-commissioning of unit after O/H Rihand ( Unit4#500 ) 25-05-2017 25-05-2017 YES Next test will be done during re-commissioning of unit after O/H Rihand ( Unit4#500 ) 11-12-2014 11-12-2014 YES Next test will be done during re-commissioning of unit after O/H Rihand ( Unit5#500 ) 11-12-2014 11-12-2014 YES Next test will be done during re-commissioning of unit after O/H SINGRAULI STPS( Unit1#200 ) - - - Not done in last three years SINGRAULI STPS( Unit2#200 ) - - - Not done in last three years SINGRAULI STPS( Unit3#200 ) - - - Not done in last three years SINGRAULI STPS( Unit4#200 ) - - - Not done in last three years SINGRAULI STPS( Unit5#200 ) - - - Not done in last three years SINGRAULI STPS( Unit6#500 ) 02.05.2018 02.05.2018 NO -- SINGRAULI STPS( Unit7#500 ) 15.07.2018 15.07.2018 NO -- UNCHAHAR I( 2 * 210 ) 29-03-2016 29-03-2016 YES -- UNCHAHAR II TPS( unit1# 210 ) 13-07-2019 13-07-2019 YES -- 10-08-2018 UNCHAHAR II TPS( unit2# 210 ) 10-08-2018 YES -- UNCHAHAR UNIT6#500 - 31.03.2017 YES -- KOLDAM HPS( 4 * 200 ) 01-07-2015 01-07-2015 YES -- DADRI GPS( 2 * 154.51) (ST- Steam Turbine) - 18-11-2015 YES -- ANTA GPS( 3 * 88.71 )(GT- Gas Turbine) 08-08-2014 08-08-2014 YES -- ANTA GPS( 1 * 153.2 )(ST- Steam Turbine) 08-08-2014 08-08-2014 YES -- 5 Aravali Power Company Private Ltd ISTPP (JHAJJAR)( 3 * 500 ) - 25-08-2015 YES -- 6 NHPC CHAMERA HPS (3*180 ) 06-08-2020 27-12-2019 YES -- CHAMERA II HPS( 3 * 100 ) 11-10-2015 11-10-2015 NO Replacement of Excitation system in two units CHAMERA III HPS( Unit1#77 ) 29-10-2015 07-01-2012 YES -- CHAMERA III HPS( Unit2,3#77 ) 29-10-2015 19-06-2012 YES -- PARBATI III HEP (Unit1# 130 ) 21-01-2016 21-01-2016 YES have been done recetly. The report on PSS turning shall be submitted seperately. DULHASTI HPS( Unit2#130 ) 21-01-2020 21-01-2020 YES -- DULHASTI HPS( Unit1#130 ) 29-12-2019 29-12-2019 YES -- URI HPS( Unit3# 120 ) 10-01-2021 10-01-2021 YES -- URI HPS( Unit4# 120 ) 15-02-2021 15-02-2021 YES -- URI HPS( Unit2# 120 ) 07-03-2016 07-03-2016 YES -- Re-tunning& Step response test shall be carriedout in 2021-22 URI-II HPS( 4 * 60 ) Mar-14 Mar-14 SALAL HPS (Unit-3,4,5,6 # 115 ) 16-12-2014 16-12-2014 YES -- KISHANGANGA( 3 * 110 ) 18-05-20 18 18-05-20 18 YES -- BAIRASIUL HPS( 3 * 60 ) 30-07-2015 30-07-2016 YES -- SEWA-II HPS( 3 * 40 ) 09-07-2016 09-07-2016 YES -- PARBATI III HEP( 4 * 130 ) 16-12-2016 16-12-2016 YES -- TANAKPUR HPS( Unit1# 31.42 ) 09-01-2015 09-01-2015 YES -- TANAKPUR HPS( Unit2,3#31.4) 24-05-2014 24-05-2014 YES -- DHAULIGANGA HPS(Unit1 ,2# 70 ) 04-05-2014 17-04-2018 YES -- DHAULIGANGA HPS(Unit3,4# 70 ) 26-06-2014 17-04-2018 YES -- 7 PUNJAB RAJPURA(NPL) TPS( 2 * 700 ) 22-04-2014 22-04-2014 YES -- 8 Rajasthan KAWAI TPS( Unt1# 660 ) 08-08-2014 08-08-2014 YES -- KAWAI TPS( Unt2# 660 ) 09-10-2014 09-10-2014 YES -- This is date of last test performed on unit 4 and 5 ,other units test were performed at KOTA TPS (2*110+2*195+3*210) 17-04-2015 17-04-2015 YES earlier date. CHHABRA TPS( Unit 1#250 ) 22-05-2018 22-05-2018 NO -- CHHABRA TPS( Unit 2,3,4#250 ) 04-10-2015 04-10-2015 NO -- CHHABRA TPS( Unit5# 660 ) 10-02-2016 10-02-2016 YES -- CHHABRA TPS( Unit6# 660 ) 7/28/2018 7/28/2018 YES -- KALISINDH TPS( Unit1# 600 ) 10-02-2016 10-02-2016 YES -- KALISINDH TPS( Unit2# 600 ) 08-02-2016 08-02-2016 YES -- KOTA TPS( Unit1#110 ) 02-01-2015 02-01-2015 NO KOTA TPS( Unit2#110 ) 16-09-2014 16-09-2014 NO -- KOTA TPS( Unit3#195) 14-10-2019 14-10-2019 NO -- KOTA TPS( Unit4#195) 06-03-2020 06-03-2020 NO -- KOTA TPS( Unit2#110 ) 18-09-2014 18-09-2014 NO -- KOTA TPS( Unit2#110 ) 16-09-2014 16-09-2014 NO -- KOTA TPS( Unit2#110 ) 16-09-2014 16-09-2014 NO -- SURATGARH TPS ( Unit1#250) 14-03-2019 14-03-2019 NO -- SURATGARH TPS ( Unit2#250) 06-02-2016 06-02-2016 Yes -- SURATGARH TPS ( Unit3,4,5,6#250) 12-01-2016 12-01-2016 Yes -- RAJWEST (IPP) LTPS( Unit1# 135 ) 26-04-2016 26-04-2016 No -- RAJWEST (IPP) LTPS( Unit2# 135 ) 14-07-2016 14-07-2016 No -- RAJWEST (IPP) LTPS( Unit3# 135 ) 03-01-2014 03-01-2014 No -- RAJWEST (IPP) LTPS( Unit4# 135 ) 03-11-2015 03-11-2015 No -- RAJWEST (IPP) LTPS( Unit5# 135 ) 21-09-2014 21-09-2014 No -- RAJWEST (IPP) LTPS( Unit6# 135 ) 14-08-2014 14-08-2014 No -- RAJWEST (IPP) LTPS( Unit7# 135 ) 20-02-2016 20-02-2016 No -- RAJWEST (IPP) LTPS( Unit8# 135 ) 11-06-2014 11-06-2014 No 9 UTTAR PRADESH ANPARA-C TPS( Unit1# 600 ) 22-08-2015 22-08-2015 Yes -- ANPARA-C TPS( Unit2# 600 ) 08-03-2016 08-03-2016 Yes -- ROSA TPS( Unit1 #300 ) 03-02-2017 03-02-2017 Yes -- ROSA TPS( Unit2# 300 ) 18/2/2018 18/2/2018 Yes -- ROSA TPS( Unit3 # 300 ) 03-02-2017 03-02-2017 Yes -- ROSA TPS( Unit4# 300 ) 03-02-2017 03-02-2017 Yes -- Anpara-A (Unit1#210) 01.05.2016 19.02.2021 No -- Anpara-A(Unit2#210) 17.11.2017 17.11.2017 No -- Anpara-A(Unit3#210) 25.09.2020 25.09.2020 No -- Overhauling is overdue since 2014 and is proposed in Nov., 2021 PSS tuning/SRT will be 07.12.2014 07.12.2014 Yes Anpara-B(Unit4#500) done at same time. Anpara-B (Unit5#500) 17.08.2014 Dec., 2019 Yes ------Anpara-D(Unit6#500) 15.11.2016 15.11.2016 No ------Anpara-D (Unit7#500) 15.04.2017 15.04.2017 No ------Obra-B(Unit9#200) 22.03.2016 22.03.2016 Yes Report enclosed. Obra-B(Unit10#200) 28.06.2016 20.06.2016 Yes Report enclosed. Obra-B (Unit11#200) 21.01.2017 21.01.2017 Yes Report enclosed. Obra-B (Unit12#200) Unit taken on load after R&M on 22 January, - PSS tuning and SRT scheduled in April, 2021. Obra-B(Unit13#200) Unit closed under R&M. - PSS tuning and SRT scheduled in April, 2021. Parichha-B(Unit3#210) 08.01.2016 08.01.2016 Yes ------Parichha-B (Unit4#210) 08.01.2016 08.01.2016 Yes ------Parichha-C (Unit5#250) 08.02.2020 08.02.2020 No ------Parichha-C(Unit3#250) 09.01.2016 09.01.2016 No ------Harduaganj (Unit8#250) 20.08.2015 20.08.2015 No ------Harduaganj (Unit3#250) 13.04.2016 13.04.2016 No ------Harduaganj(Unit#105) 16.07.2021 16.07.2021 yes Report enclosed. Harduaganj(Unit#250) 16.07.2021 16.07.2021 yes Report enclosed. Sr. Date Elements Remarks No andTime Name 1. 400 KV Alaknanda GVK(UPC)-Srinagar(UK) (UK) Ckt-1 2. 400 KV Alaknanda GVK(UPC)-Srinagar(UK) (UK) Ckt-2 3. 400 KV Alaknanda GVK(UPC)- Vishnuprayag(JP) (UP) Ckt-1 4. 400 KV Alaknanda GVK(UPC)- Muzaffarnagar (UP) Ckt-1 Y-N phase to earth fault is 5. 220 KV Singoli Bhatwari(Singoli(LTUHP))- observed. Fault current was Srinagar(UK) (PTCUL) Ckt-2 20 July 2.3kA and fault distance was 6. 220 KV Singoli Bhatwari(Singoli(LTUHP))- 2021at 81.89km from Alaknanda 1 Srinagar(UK) (PTCUL) Ckt-1 14:39 Hrs end & 111.49km from 7. 400KV Muzaffarnagar(UP)- Muzaffarnagar end (Fault Vishnuprayag(JP) (UP) Ckt-1 was in Z-1 from both end.) 8. 110 MW Vishnuparyag HPS - UNIT 3 9. 110 MW Vishnuparyag HPS - UNIT 2 10. 110 MW Vishnuparyag HPS - UNIT 4 11. 110 MW Vishnuparyag HPS - UNIT 12. 82.5 MW Alakhanda HEP - UNIT 1 13. 82.5 MW Alakhanda HEP - UNIT 3 14. 82.5 MW Alakhanda HEP - UNIT 2 15. 82.5 MW Alakhanda HEP - UNIT 4 16. 33MW Singoli Bhatwari UNIT 1 17. 33MW Singoli Bhatwari UNIT 2 18. 33MW Singoli Bhatwari UNIT 3 1. 400KV Muzaffarnagar(UP)- Vishnuprayag(JP) (UP) Ckt-1 2. 400/220 kV 315 MVA ICT 1 at Muzaffarnagar(UP) 3. 400/220 kV 315 MVA ICT 3 at Muzaffarnagar(UP) Differential protection 4. 400/220 kV 500 MVA ICT 4 at operation on blast of R- Muzaffarnagar(UP) ph CT of ICT 3, Bus bar-1 5. 400 KV Meerut(PG)-Muzaffarnagar(UP) 07 Aug protection operation, B- (PG) Ckt-1 2021 at N phase to earth fault 2 6. 400 KV Muzaffarnagar-Ataur (UP) Ckt-1 03:02Hrs on 400 KV Alaknanda- 7. 400 KV Roorkee(PG)-Muzaffarnagar(UP) Muzaffarnagar Ckt-1 (PTCUL) Ckt-1 fault distance was 8. 400 KV Alaknanda GVK(UPC)-Srinagar(UK) 116meter(Z-1) from (UK) Ckt-1 Muzaffarnagar end. 9. 400 KV Alaknanda GVK(UPC)-Srinagar(UK) (UK) Ckt-2 10. 400 KV Alaknanda GVK(UPC)- Vishnuprayag(JP) (UP) Ckt-1 11. 400 KV Alaknanda GVK(UPC)- Muzaffarnagar (UP) Ckt-1 12. 220 KV Singoli Bhatwari(Singoli(LTUHP))- Srinagar(UK) (PTCUL) Ckt-2 13. 220 KV Singoli Bhatwari(Singoli(LTUHP))- Srinagar(UK) (PTCUL) Ckt-1 14. 110 MW Vishnuparyag HPS - UNIT 3 15. 110 MW Vishnuparyag HPS - UNIT 2 16. 110 MW Vishnuparyag HPS - UNIT 4 17. 110 MW Vishnuparyag HPS - UNIT 18. 82.5 MW Alakhanda HEP - UNIT 1 19. 82.5 MW Alakhanda HEP - UNIT 3 20. 82.5 MW Alakhanda HEP - UNIT 2 21. 82.5 MW Alakhanda HEP - UNIT 4 22. 33MW Singoli Bhatwari UNIT 1 23. 33MW Singoli Bhatwari UNIT 2 24. 33MW Singoli Bhatwari UNIT 3 Fig:PMUphasevoltageplotofincident(20thJul2021at14:39hrs) Fig: PMU phase voltage plot of incident (07th Aug2021 at 03:02 hrs)