Global Invitation for selection of Transmission Service Provider to establish Transmission system for the project namely “Transmission System for Proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)”

REC POWER DEVELOPMENT AND CONSULTANCY LIMITED आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड (A wholly owned subsidiary of REC Ltd.) (आरईसी िलिमटेड के पूण वािमव क सहायक कंपनी) GLOBAL INVITATION (Through e-bidding Only) वैिक आमंण (इलेॉिनक बोली के मायम से) FOR SELECTION OF TRANSMISSION SERVICE PROVIDER THROUGH TARIFF BASED टैरफ के जरए ितयोिगता बोली (टीबीसीबी) िया के मायम से 01 (एक) अंतर-रायीय पारेषण परयोजना COMPETITIVE BIDDING (TBCB) PROCESS ON BUILD, OWN, OPERATE AND TRANSFER के िनमाण, वािमव, चालन और हतांतरण (बीओओटी) आधारत पारेषण सेवा दाता के चयन के िलए (BOOT) BASIS FOR 01 (ONE) INTER – STATE TRANSMISSION PROJECT आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड, नई िदली, भारत (आरईसी िलिमटेड के पणू वािमव क सहायक REC Power Development and Consultancy Limited, New Delhi, India (a wholly owned subsidiary of REC कंपनी - एक महारन कीय सावजिनक उपम) नीच ेउिलिखत पारेषण परयोजना क थापना हते ुटी.बी.सी.बी. के Limited, a Maharatna Central Public Sector Undertaking) invites proposal for setting up of the below अतं गत िनमाण, वािमव, चालन और हतातं रण (बटू) के आधार पर ताव हते ुअनरुोध (आरएफपी) एक चरण दो mentioned transmission project through TBCB process on Build, Own, Operate and Transfer (BOOT) िलफाफे वाली िया के तहत ताव आमिंत करता ह।ै इछुक बोलीदाता कृपया हमारी वेबसाइट्स basis following single stage two envelope process of "Request for Proposal (RFP)". Interested bidders www.recindia.nic.in तथा www.recpdcl.in पर 03.02.2026 से उपलध “ताव हते ुअनरुोध” (आरएफपी) may refer to the Request for Proposal (RFP) notifications and RFP documents available on our websites अिधसचू ना तथा आरएफपी दतावेज़ का अवलोकन करे। www.recpdcl.in & www.recindia.nic.in w.e.f. 03.02.2026. बोलीदाता, आरएफपी दतावेज सभी काय िदवस म 10:30 बजे (भा.मा.स) से 16:00 बजे (भा.मा.स) के बीच The bidders may obtain the RFP documents on all working days between 10:30 hours (IST) to 16:00 (03.02.2026 से ताव जमा करने क ितिथ से एक िदन पहले तक) हमारी वेबसाइट्स www.recindia.nic.in और hours (IST) from 03.02.2026 to one day prior to bid submission date on payment of non-refundable fee of www.recpdcl.in पर उपलध परयोजना के आरएफपी दतावेज म िदए गए िववरण के अनसु ार अितदये गैर-वापसी Rs. 5,00,000/- (Rupees Five Lakh Only) or US$ 7000 (US Dollars Seven Thousand Only) + 18% GST as योय शुक (₹5,00,000/- (पांच लाख पए केवल) या $7000 (यएूस डालर सात हजार केवल) + 18% जीएसटी) के per details provided in the RFP document available on the websites www.recpdcl.in & www.recindia.nic.in. भगुतान पर ा कर सकते ह।ै The Request for Proposal (RFP) documents can also be downloaded from our websites www.recpdcl.in आरएफपी दतावेज हमारी वेबसाइट्स www.recindia.nic.in तथा www.recpdcl.in से भी डाउनलोड िकया जा & www.recindia.nic.in, however, in such cases interested parties can submit Response to RFP only on सकता ह।ै तथािप, ऐसे मामले म इछुक पाट आरएफपी दतावेज म िदए गए िववरण के अनसु ार अितदये गैर-वापसी योय submission of non-refundable fee of Rs. 5,00,000/-(Rupees Five Lakh Only) or US$ 7000 (US Dollars शुक (₹5,00,000/- (पांच लाख पए केवल) या $7000 (यएूस डालर सात हजार केवल) + 18% जीएसटी) का अलग Seven Thousand Only) + 18% GST as per details provided in the RFP document. The survey report & से भगुतान करने पर ही आरएफपी के उर म ताव जमा कर सकते ह। सव रपोट एवं आरएफपी दतावेज के पीकरण clarifications to RFP document shall be issued to those bidders, who have obtained/purchased RFP उह बोलीदाताओ ंको जारी िकया जाएगा, िजहने अपेित शुक का भगुतान करके आरएफपी दतावेज ा िकया या documents by paying requisite fee. The important timelines in this regard are as follows: खरीदा ह।ै इस सदभ म महवपणू समय-सीमा इस कार ह:ै Last Date for Last Date for Details of S Nr o. . Name of Project clas re ifie ck ain tig o ns Res su pb om ni ss es i to on R o Ff P ResO pp oe nn si en g to o Rf FP सम .ं. परयोजना का नाम मप ंग वी ाक ने र कण मआ र ए तफ ावप ी ज क मे ाउ कर खआ ोलरए नफ े कपी ा िव वत राव ण अंितम ितिथ अंितम ितिथ 1. Transmission system for proposed Green 23.02.2026 07.04.2026 up to 07.04.2026 at 1. वाईजैग े, आं दशे (चरण-I) म 23.02.2026 07.04.2026, 1500 07.04.2026 को Hydrogen / Green Ammonia projects in 1500 Hrs (IST) 1530 Hrs (IST) तािवत हरत हाइोजन/हरत अमोिनया बजे तक (भा.मा.स) 1530 बज े(भा.मा.स) Vizag area, Andhra Pradesh (Phase-I) परयोजनाओ ंके िलए पारेषण णाली All corrigenda, addenda, amendments, time extensions, etc. to the RFP will be hosted on our websites www.recpdcl.in & www.recindia.nic.in. Bidders should regularly visit our websites to keep themselves बोली म सभी शिुप, अनशु ेष, संशोधन, समय बढ़ाना आिद हमारी वेबसाइट्स www.recindia.nic.in तथा updated. www.recpdcl.in पर होट िकए जाएगंे। नवीनतम जानकारी के िलए हमारी वेबसाइट का िनयिमत प से अवलोकन करते रह।े Note: RECPDCL reserves the right to cancel or modify the process without assigning any reason and without any liability. This is not an offer. नोट: आरईसीपीडीसीएल के पास िबना कोई कारण बताए तथा िबना िकसी बायता के बोली िया को र या संशोिधत Chief Executive Officer करने का अिधकार सरुित ह।ै यह कोई पेशकश नह ह।ै मु य कायपालक अिधकारी REC Power Development and Consultancy Ltd. आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi-110003, India कोर - 4, कोप कॉलेस, लोधी रोड, नई िदली - 110003, भारत Bid Process Coordinator An Initiative of Initiative Partner पहलकता पहलकता भागीदार बोली िया समवयक REC Power Development and Ministry of Power Central Electricity िवघुत मंालय Consultancy Limited Government of India Authority आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड भारत सरकार कीय िवघुत ािधकरण ऊजा ही जीवन है, इसे बचाए ं। Give a missed call on toll free number 18002003004 to get our Apps ऊजा ही जीवन है, इसे बचाए ं। Give a missed call on toll free number 18002003004 to get our Apps Size : 8(W) x 11(H) - Colour (English) Size : 8(W) x 11(H) - Colour (Hindi) REC POWER DEVELOPMENT AND CONSULTANCY LIMITED (A wholly owned subsidiary of REC Ltd.) GLOBAL INVITATION (Through e-bidding Only) FOR SELECTION OF TRANSMISSION SERVICE PROVIDER THROUGH TARIFF BASED COMPETITIVE BIDDING (TBCB) PROCESS ON BUILD, OWN, OPERATE AND TRANSFER (BOOT) BASIS FOR 01 (ONE) INTER – STATE TRANSMISSION PROJECT REC Power Development and Consultancy Limited, New Delhi, India (a wholly owned subsidiary of REC Limited, a Maharatna Central Public Sector Undertaking) invites proposal for setting up of the below mentioned transmission project through TBCB process on Build, Own, Operate and Transfer (BOOT) basis following single stage two envelope process of "Request for Proposal (RFP)". Interested bidders may refer to the Request for Proposal (RFP) notifications and RFP documents available on our websites www.recpdcl.in & www.recindia.nic.in w.e.f. 03.02.2026. The bidders may obtain the RFP documents on all working days between 10:30 hours (IST) to 16:00 hours (IST) from 03.02.2026 to one day prior to bid submission date on payment of non-refundable fee of Rs. 5,00,000/-(Rupees Five Lakh Only) or US$ 7000 (US Dollars Seven Thousand Only) + 18% GST as per details provided in the RFP document available on the websites www.recpdcl.in & www.recindia.nic.in. The Request for Proposal (RFP) documents can also be downloaded from our websites www.recpdcl.in & www.recindia.nic.in, however, in such cases interested parties can submit Response to RFP only on submission of non-refundable fee of Rs. 5,00,000/-(Rupees Five Lakh Only) or US$ 7000 (US Dollars Seven Thousand Only) + 18% GST as per details provided in the RFP document. The survey report & clarifications to RFP document shall be issued to those bidders, who have obtained/purchased RFP documents by paying requisite fee. The important timelines in this regard are as follows: Sr. Name of Project Last Date for seeking Last Date for submissionDetails of Opening of No. clarications of Response to RFP Response to RFP 1. Transmission system for proposed Green 23.02.2026 07.04.2026 up to 07.04.2026 at Hydrogen / Green Ammonia projects in Vizag 1500 Hrs (IST) 1530 Hrs (IST) area, Andhra Pradesh (Phase-I) All corrigenda, addenda, amendments, time extensions, etc. to the RFP will be hosted on our websites www.recpdcl.in & www.recindia.nic.in. Bidders should regularly visit our websites to keep themselves updated. Note: RECPDCL reserves the right to cancel or modify the process without assigning any reason and without any liability. This is not an offer. Chief Executive Officer REC Power Development and Consultancy Ltd. Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi-110003, India Bid Process Coordinator An Initiative of Initiative Partner Ministry of Power Central Electricity REC Power Development and Consultancy Limited Government of India Authority ऊजा ही जीवन है, इसे बचाए ं। Give a missed call on toll free number 18002003004 to get our Apps Size : 11.2(W) x 10(H) - English Financial TimesREC POWER DEVELOPMENT AND CONSULTANCY LIMITED आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड (A wholly owned subsidiary of REC Ltd.) (आरईसी िलिमटेड के पूण वािमव क सहायक कंपनी) GLOBAL INVITATION (Through e-bidding Only) वैिक आमंण (इलेॉिनक बोली के मायम से) FOR SELECTION OF TRANSMISSION SERVICE PROVIDER THROUGH TARIFF BASED टैरफ के जरए ितयोिगता बोली (टीबीसीबी) िया के मायम से 01 (एक) अंतर-रायीय पारेषण परयोजना COMPETITIVE BIDDING (TBCB) PROCESS ON BUILD, OWN, OPERATE AND TRANSFER के िनमाण, वािमव, चालन और हतांतरण (बीओओटी) आधारत पारेषण सेवा दाता के चयन के िलए (BOOT) BASIS FOR 01 (ONE) INTER – STATE TRANSMISSION PROJECT आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड, नई िदली, भारत (आरईसी िलिमटेड के पणू वािमव क सहायक REC Power Development and Consultancy Limited, New Delhi, India (a wholly owned subsidiary of REC कंपनी - एक महारन कीय सावजिनक उपम) नीच ेउिलिखत पारेषण परयोजना क थापना हते ुटी.बी.सी.बी. के Limited, a Maharatna Central Public Sector Undertaking) invites proposal for setting up of the below अतं गत िनमाण, वािमव, चालन और हतातं रण (बटू) के आधार पर ताव हते ुअनरुोध (आरएफपी) एक चरण दो mentioned transmission project through TBCB process on Build, Own, Operate and Transfer (BOOT) िलफाफे वाली िया के तहत ताव आमिंत करता ह।ै इछुक बोलीदाता कृपया हमारी वेबसाइट्स basis following single stage two envelope process of "Request for Proposal (RFP)". Interested bidders www.recindia.nic.in तथा www.recpdcl.in पर 03.02.2026 से उपलध “ताव हते ुअनरुोध” (आरएफपी) may refer to the Request for Proposal (RFP) notifications and RFP documents available on our websites अिधसचू ना तथा आरएफपी दतावेज़ का अवलोकन करे। www.recpdcl.in & www.recindia.nic.in w.e.f. 03.02.2026. बोलीदाता, आरएफपी दतावेज सभी काय िदवस म 10:30 बजे (भा.मा.स) से 16:00 बजे (भा.मा.स) के बीच The bidders may obtain the RFP documents on all working days between 10:30 hours (IST) to 16:00 (03.02.2026 से ताव जमा करने क ितिथ से एक िदन पहले तक) हमारी वेबसाइट्स www.recindia.nic.in और hours (IST) from 03.02.2026 to one day prior to bid submission date on payment of non-refundable fee of www.recpdcl.in पर उपलध परयोजना के आरएफपी दतावेज म िदए गए िववरण के अनसु ार अितदये गैर-वापसी Rs. 5,00,000/- (Rupees Five Lakh Only) or US$ 7000 (US Dollars Seven Thousand Only) + 18% GST as योय शुक (₹5,00,000/- (पांच लाख पए केवल) या $7000 (यएूस डालर सात हजार केवल) + 18% जीएसटी) के per details provided in the RFP document available on the websites www.recpdcl.in & www.recindia.nic.in. भगुतान पर ा कर सकते ह।ै The Request for Proposal (RFP) documents can also be downloaded from our websites www.recpdcl.in आरएफपी दतावेज हमारी वेबसाइट्स www.recindia.nic.in तथा www.recpdcl.in से भी डाउनलोड िकया जा & www.recindia.nic.in, however, in such cases interested parties can submit Response to RFP only on सकता ह।ै तथािप, ऐसे मामले म इछुक पाट आरएफपी दतावेज म िदए गए िववरण के अनसु ार अितदये गैर-वापसी योय submission of non-refundable fee of Rs. 5,00,000/-(Rupees Five Lakh Only) or US$ 7000 (US Dollars शुक (₹5,00,000/- (पांच लाख पए केवल) या $7000 (यएूस डालर सात हजार केवल) + 18% जीएसटी) का अलग Seven Thousand Only) + 18% GST as per details provided in the RFP document. The survey report & से भगुतान करने पर ही आरएफपी के उर म ताव जमा कर सकते ह। सव रपोट एवं आरएफपी दतावेज के पीकरण clarifications to RFP document shall be issued to those bidders, who have obtained/purchased RFP उह बोलीदाताओ ंको जारी िकया जाएगा, िजहने अपेित शुक का भगुतान करके आरएफपी दतावेज ा िकया या documents by paying requisite fee. The important timelines in this regard are as follows: खरीदा ह।ै इस सदभ म महवपणू समय-सीमा इस कार ह:ै Last Date for Last Date for Details of S Nr o. . Name of Project clas re ifie ck ain tig o ns Res su pb om ni ss es i to on R o Ff P ResO pp oe nn si en g to o Rf FP सम .ं. परयोजना का नाम मप ंग वी ाक ने र कण मआ र ए तफ ावप ी ज क मे ाउ कर खआ ोलरए नफ े कपी ा िव वत राव ण अंितम ितिथ अंितम ितिथ 1. Transmission system for proposed Green 23.02.2026 07.04.2026 up to 07.04.2026 at 1. वाईजैग े, आं दशे (चरण-I) म 23.02.2026 07.04.2026, 1500 07.04.2026 को Hydrogen / Green Ammonia projects in 1500 Hrs (IST) 1530 Hrs (IST) तािवत हरत हाइोजन/हरत अमोिनया बजे तक (भा.मा.स) 1530 बज े(भा.मा.स) Vizag area, Andhra Pradesh (Phase-I) परयोजनाओ ंके िलए पारेषण णाली All corrigenda, addenda, amendments, time extensions, etc. to the RFP will be hosted on our websites www.recpdcl.in & www.recindia.nic.in. Bidders should regularly visit our websites to keep themselves बोली म सभी शिुप, अनशु ेष, संशोधन, समय बढ़ाना आिद हमारी वेबसाइट्स www.recindia.nic.in तथा updated. www.recpdcl.in पर होट िकए जाएगंे। नवीनतम जानकारी के िलए हमारी वेबसाइट का िनयिमत प से अवलोकन करते रह।े Note: RECPDCL reserves the right to cancel or modify the process without assigning any reason and without any liability. This is not an offer. नोट: आरईसीपीडीसीएल के पास िबना कोई कारण बताए तथा िबना िकसी बायता के बोली िया को र या संशोिधत Chief Executive Officer करने का अिधकार सरुित ह।ै यह कोई पेशकश नह ह।ै मु य कायपालक अिधकारी REC Power Development and Consultancy Ltd. आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi-110003, India कोर - 4, कोप कॉलेस, लोधी रोड, नई िदली - 110003, भारत Bid Process Coordinator An Initiative of Initiative Partner पहलकता पहलकता भागीदार बोली िया समवयक REC Power Development and Ministry of Power Central Electricity िवघुत मंालय Consultancy Limited Government of India Authority आरईसी पावर डेवलपमट एडं कंसटसी िलिमटेड भारत सरकार कीय िवघुत ािधकरण ऊजा ही जीवन है, इसे बचाए ं। Give a missed call on toll free number 18002003004 to get our Apps ऊजा ही जीवन है, इसे बचाए ं। Give a missed call on toll free number 18002003004 to get our Apps Size : 8(W) x 11(H) - Colour (English) Size : 8(W) x 11(H) - Colour (Hindi) REC POWER DEVELOPMENT AND CONSULTANCY LIMITED (A wholly owned subsidiary of REC Ltd.) GLOBAL INVITATION (Through e-bidding Only) FOR SELECTION OF TRANSMISSION SERVICE PROVIDER THROUGH TARIFF BASED COMPETITIVE BIDDING (TBCB) PROCESS ON BUILD, OWN, OPERATE AND TRANSFER (BOOT) BASIS FOR 01 (ONE) INTER – STATE TRANSMISSION PROJECT REC Power Development and Consultancy Limited, New Delhi, India (a wholly owned subsidiary of REC Limited, a Maharatna Central Public Sector Undertaking) invites proposal for setting up of the below mentioned transmission project through TBCB process on Build, Own, Operate and Transfer (BOOT) basis following single stage two envelope process of "Request for Proposal (RFP)". Interested bidders may refer to the Request for Proposal (RFP) notifications and RFP documents available on our websites www.recpdcl.in & www.recindia.nic.in w.e.f. 03.02.2026. The bidders may obtain the RFP documents on all working days between 10:30 hours (IST) to 16:00 hours (IST) from 03.02.2026 to one day prior to bid submission date on payment of non-refundable fee of Rs. 5,00,000/-(Rupees Five Lakh Only) or US$ 7000 (US Dollars Seven Thousand Only) + 18% GST as per details provided in the RFP document available on the websites www.recpdcl.in & www.recindia.nic.in. The Request for Proposal (RFP) documents can also be downloaded from our websites www.recpdcl.in & www.recindia.nic.in, however, in such cases interested parties can submit Response to RFP only on submission of non-refundable fee of Rs. 5,00,000/-(Rupees Five Lakh Only) or US$ 7000 (US Dollars Seven Thousand Only) + 18% GST as per details provided in the RFP document. The survey report & clarifications to RFP document shall be issued to those bidders, who have obtained/purchased RFP documents by paying requisite fee. The important timelines in this regard are as follows: Sr. Name of Project Last Date for seeking Last Date for submissionDetails of Opening of No. clarications of Response to RFP Response to RFP 1. Transmission system for proposed Green 23.02.2026 07.04.2026 up to 07.04.2026 at Hydrogen / Green Ammonia projects in Vizag 1500 Hrs (IST) 1530 Hrs (IST) area, Andhra Pradesh (Phase-I) All corrigenda, addenda, amendments, time extensions, etc. to the RFP will be hosted on our websites www.recpdcl.in & www.recindia.nic.in. Bidders should regularly visit our websites to keep themselves updated. Note: RECPDCL reserves the right to cancel or modify the process without assigning any reason and without any liability. This is not an offer. Chief Executive Officer REC Power Development and Consultancy Ltd. Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi-110003, India Bid Process Coordinator An Initiative of Initiative Partner Ministry of Power Central Electricity REC Power Development and Consultancy Limited Government of India Authority ऊजा ही जीवन है, इसे बचाए ं। Give a missed call on toll free number 18002003004 to get our Apps Size : 11.2(W) x 10(H) - English Financial TimesRFP for Selection of Bidder as Transmission Service Provider SINGLE STAGE REQUEST FOR PROPOSAL DOCUMENT FOR SELECTION OF BIDDER AS TRANSMISSION SERVICE PROVIDER THROUGH TARIFF BASED COMPETITIVE BIDDING PROCESS TO ESTABLISH INTER-STATE TRANSMISSION SYSTEM UNDER TRANSMISSION SYSTEM FOR PROPOSED GREEN HYDROGEN / GREEN AMMONIA PROJECTS IN VIZAG AREA, ANDHRA PRADESH (PHASE-I) ISSUED BY REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) Registered Office: Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi – 110 003 Email: vijay.kulkarni@recpdcl.in & tbcb@recpdcl.in 03.02.2026 REC Power Development and Consultancy Limited 1RFP for Selection of Bidder as Transmission Service Provider REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi – 110 003 Request for Proposal Document for selection of Bidder as Transmission Service Provider through tariff based competitive bidding process to establish Inter-State Transmission system for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” is issued by REC Power Development and Consultancy Limited. This RFP document is issued to - M/s. _______________________ ___________________________ ___________________________ ___________________________ ___________________________ Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) Email: ……………………………………. Place: …………………………………… Date: …………………………………… Signature: …………………………………… REC Power Development and Consultancy Limited 2RFP for Selection of Bidder as Transmission Service Provider REQUEST FOR PROPOSAL NOTIFICATION REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi – 110 003 1. Ministry of Power, Government of India vide its Gazette Notification No. 5827 [F. No. 15/3/2018-Trans-Part (4)] dated 26.12.2025 has notified REC Power Development and Consultancy Limited (RECPDCL) to be the Bid Process Coordinator (BPC) for the purpose of Selection of Bidder as Transmission Service Provider to establish Inter-State transmission system for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process. 2. REC Power Development and Consultancy Limited (hereinafter referred to as BPC) hereby invites all prospective Bidders for issue of Request for Proposal (RFP) for selection of Bidder as Transmission Service Provider (TSP) on the basis of international competitive bidding in accordance with the “Tariff Based Competitive Bidding Guidelines for Transmission Service” and “Guidelines for Encouraging Competition in Development of Transmission Projects” issued by Government of India, Ministry of Power under section – 63 of The Electricity Act, 2003 and as amended from time to time. The responsibility of the TSP would be to establish Inter-State Transmission system - Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” (hereinafter referred to as 'Project’) on build, own, operate & transfer basis and to provide transmission service: Scheduled COD in Sl. No. Scope of the Transmission Scheme months from Effective Date Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) GIS substation with 1x330 MVAr (765 kV) bus reactor with space provision for establishment of 220 kV switchyard  765/400 kV, 1500 MVA, ICTs – 4 Nos. (13x500 MVA incl. 1 spare unit) 1.  765 kV ICT bay – 4 Nos. 30 Months  400 kV ICT bay – 4 Nos.  765 kV line bays – 2 Nos. (at Pendurthi (Vizag) GIS for termination of Pendurthi (Vizag) – Srikakulam 765 kV D/c line)  765 kV line bays – 2 Nos. with provision of SLR (at Pendurthi (Vizag) GIS for termination of Khammam- II – Pendurthi (Vizag) –765 kV D/c line) REC Power Development and Consultancy Limited 3RFP for Selection of Bidder as Transmission Service Provider  765 kV, 330 MVAr Bus Reactors – 1 No. (4x110 MVAr inc. 1 switchable spare unit for both bus reactor and line reactor)  765 kV Bus Reactor bays – 1 No.  400 kV line bays – 4 Nos. (at Pendurthi (Vizag) GIS for termination of LILO of Kalpakka – Maradam 400 kV (quad) D/c line at Pendurthi) Future Space Provisions:  765/400 kV, 1500 MVA, ICTs – 2 Nos.  765 kV ICT bays – 2 Nos.  400 kV ICT bays – 2 Nos.  765 kV line bays – 8 Nos. (with provision for SLR)  400 kV line bays – 12 Nos. (with provision for SLR)  400 kV Bus Sectionalizer : 1 set Future Space Provisions for 220kV switchyard:  400/220 kV, 500 MVA, ICTs – 10 Nos.  400 kV ICT bays – 10 Nos.  220 kV ICT bays – 10 Nos.  220 kV line bays – 16 Nos.  220 kV Bus Sectionalizer: 3 set  220 kV Bus Coupler (BC) Bay – 4 Nos.  220 kV Transfer Bus Coupler (TBC) Bay – 4 Nos. + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS with control switching arrangement for proposed 1x330 MVAr bus reactor Space provision for 2nd + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS 2.  + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS with control switching arrangement for proposed 1x330 MVAr bus reactor – 1 set  400 kV bay – 1 No. Pendurthi (Vizag) – Srikakulam 765 kV D/c line with 330 MVAr SLR (convertible) at Srikakulam end on both 3. circuits REC Power Development and Consultancy Limited 4RFP for Selection of Bidder as Transmission Service Provider  765 kV line along with SLR GIS bays at Srikakulam - The D/c line to be terminated in the future line bays with SLR proposed under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid”  765 kV, 330 MVAr SLR at Srikakulam – 2 Nos. (7x110 MVAr switchable units inc. 1 switchable spare unit) LILO of Kalpakka – Maradam 400 kV (quad) D/c line at 4. Pendurthi Establishment of 3x1500 MVA, 765/400 kV Khammam- II substation with 1x330 MVAr (765 kV) bus reactor with space provision for establishment of 220 kV switchyard  765/400 kV, 1500 MVA, ICTs – 3 Nos. (10x500 MVA incl. 1 spare unit)  765 kV ICT bay – 3 Nos.  400 kV ICT bay – 3 Nos.  765 kV line bays – 4 Nos. (at Khammam-II for termination of Khammam-II – Pendurthi and Khammam-II – Warangal New 765 kV D/c lines)  765 kV, 330 MVAr Bus Reactors – 1 No. (4x110 MVAr inc. 1 switchable spare unit for both bus reactor and line reactor)  765 kV Bus Reactor bays – 1 No.  400 kV line bays – 2 Nos. (at Khammam-II for termination of Khammam-II – Khammam (existing) 5. 400 kV (quad) D/c line) Future Space Provisions:  765/400 kV, 1500 MVA, ICTs – 3 Nos.  765 kV ICT bays – 3 Nos.  400 kV ICT bays – 3 Nos.  765 kV line bays – 8 Nos. (with provision for SLR)  400 kV line bays – 10 Nos. (with provision for SLR)  400 kV Bus Sectionalizer: 1 set Future Space Provisions for 220kV switchyard:  400/220 kV, 500 MVA, ICTs – 10 Nos.  400 kV ICT bays – 10 Nos.  220 kV ICT bays – 10 Nos.  220 kV line bays – 16 Nos.  220 kV Bus Sectionalizer: 3 set  220 kV Bus Coupler (BC) Bay – 4 Nos. REC Power Development and Consultancy Limited 5RFP for Selection of Bidder as Transmission Service Provider  220 kV Transfer Bus Coupler (TBC) Bay – 4 Nos Khammam-II – Warangal New 765 kV D/c line 6.  765 kV line bays – 2 Nos. (at Warangal New) Khammam-II – Pendurthi (Vizag) 765 kV D/c line with 330 MVAr SLR (convertible) at both ends on both circuits  765 kV, 330 MVAr SLR at Pendurthi (Vizag) – 2 Nos. (6x110 MVAr switchable units) 7.  Switching Equipment for 765 kV SLR at Pendurthi (Vizag) GIS – 2 Nos  765 kV, 330 MVAr SLR at Khammam-II – 2 Nos. (6x110 MVAr switchable units)  Switching Equipment for 765 kV SLR at Khammam- II PS – 2 Nos Khammam-II – Khammam (existing) 400 kV (quad) D/c line 8.  400kV line bays – 2 Nos. (at Khammam (existing)) Note: i. Bay(s) required for completion of diameter (GIS) in one-and-half breaker scheme shall also be executed by the TSP. ii. POWERGRID to provide space (free of cost) for 765 kV line along with SLR GIS bays at Srikakulam - The D/c line to be terminated in the future line bays with SLR proposed under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid” iii. POWERGRID to provide space (free of cost) for 2 Nos. of 400 kV line bays at Khammam for termination of Khammam-II – Khammam (existing) 400 kV (quad) D/c line iv. TSP of Warangal New S/s (Adani) to provide space (free of cost) for 2 Nos. of 765 kV line bays with provision of SLR at Warangal New S/s for termination of Khammam-II – Warangal New 765 kV D/c line 3. The TSP shall ensure that design, construction and testing of all equipment, facilities, components and systems of the Project shall be in accordance with the provisions of the Transmission Service Agreement and applicable Rules/ Regulations, Orders and Guidelines issued by the Central Government. 4. Transmission License: The TSP shall obtain the Transmission License from the Commission. REC Power Development and Consultancy Limited 6RFP for Selection of Bidder as Transmission Service Provider 5. Bidding Process: The Transmission Service Provider shall be selected through tariff based competitive bidding process for the Project based on meeting stipulated Qualification Requirements prescribed in Clause 2.1 of Section 2 of RFP and the lowest Quoted Transmission Charges discovered from Final Offers quoted during the e-reverse bidding. The selection of the TSP shall be subject to obtaining Transmission License from the Commission, which, after expiry, may be further extended by such period as deemed appropriate by the Commission under powers vested with it to amend the conditions of the Transmission License. The entire bidding process shall be conducted on electronic platform created by MSTC Limited. The Bid shall be a single stage two envelope bid comprising the Technical Bid and the Financial Bid. The Bidders shall submit the Bid online through the electronic bidding platform. In addition to the online submission, the Bidder with lowest Final Offer will be required to submit original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B before issuance of LoI. There shall be no physical submission of the Financial Bid. The Technical Bid shall be opened first and the Financial Bid of only the bidders who have qualified in the Technical Bid shall be opened. The Financial Bid will comprise two rounds. In the first round the Initial Offer of the responsive bids would be opened and Quoted Transmission Charges of Initial Offer shall be ranked on the basis of ascending order. The Bidders, in the first fifty per cent of the ranking (with any fraction rounded off to higher integer) or four Bidders, whichever is higher, shall qualify for participating in the electronic reverse auction stage and submit their Final Offer. 6. The objective of the bidding process is to select a Successful Bidder pursuant to this RFP, who shall acquire one hundred percent (100%) of the equity shares of ……………… (Insert the name of SPV) along with all its related assets and liabilities as per the provisions of the Share Purchase Agreement, at the Acquisition Price to be intimated by the BPC, twenty (20) days prior to the Bid Deadline. The ……………… (Insert the name of SPV), of which one hundred percent (100%) equity shares will be acquired by the Selected Bidder, shall be responsible as the TSP, for ensuring that it undertakes ownership, financing, development, design, engineering, procurement, construction, commissioning, operation and maintenance of the Project, and to provide Transmission Service as per the terms of the RFP Project Documents. The TSP shall ensure transfer of all project assets along with substation land, right of way and clearances to CTU or its successors or an agency as decided by the Central Government after 35 years from COD of project at zero cost and free from any encumbrance and liability. The transfer shall be completed within 90 days after 35 years from COD of project failing which CTU shall be entitled to take over the project assets Suo moto. 7. Commencement of Transmission Service: The Bidder shall have to commence Transmission Service in accordance with the provisions of the Transmission Service Agreement. 8. Transmission Charges: The Transmission Charges shall be payable by the Designated ISTS Customers in Indian Rupees through the CTU as per Central Electricity Regulatory REC Power Development and Consultancy Limited 7RFP for Selection of Bidder as Transmission Service Provider Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time. Bidders shall quote the Transmission Charges as per the pre- specified structure, as mentioned in the RFP. 9. Issue of RFP document: The detailed terms and conditions for qualification and selection of the Transmission Service Provider for the Project and for submission of Bid are indicated in the RFP document. All those interested in purchasing the RFP document may respond in writing to Chief Executive Officer, vijay.kulkarni@recpdcl.in& tbcb@recpdcl.in at the address given in para 12 below with a non-refundable fee of Rs. 5,00,000/- (Rupees Five Lakh Only) or US$ 7,000 (US Dollars Seven Thousand Only) plus GST @18%, to be paid latest by 06.04.2026 via electronic transfer to the following Bank Account: Bank Name, Address & ICICI Bank Branch 9A, Phelps Building, Inner Circle, Connaught Place, New Delhi-110001 Bank Account Name REC Power Development & Consultancy Limited Bank Account No 000705041275 Bank IFSC Code No ICIC0000007 Immediately after issuance of RFP document, the Bidder shall submit the Pre-Award Integrity Pact in the format as prescribed in Annexure B, which shall be applicable for and during the bidding process, duly signed on each page by any whole-time Director/ Authorized Signatory, duly witnessed by two persons, and shall be submitted by the Bidder in two (2) originals in a separate envelope, duly superscripted with Pre-Award Integrity Pact. The Bidder shall submit the Pre-Award Integrity Pact on non-judicial stamp paper of Rs. 100/- each duly purchased from the National Capital Territory of Delhi. In case the Bidder is in a consortium, the Pre- Award Integrity Pact shall be signed and submitted by each member of the Consortium separately. The RFP document shall be issued to the Bidders on any working day from 03.02.2026 to 06.04.2026 between 1030 hours (IST) to 1600 hours (IST). The BPC, on written request and against payment of the above mentioned fee by any Bidder shall promptly dispatch the RFP document to such Bidder by registered mail/ air mail. BPC shall, under no circumstances, be held responsible for late delivery or loss of documents so mailed. 10. Receipt and opening of Bid: The Bid must be uploaded online through the electronic bidding platform on or before 1500 hours (IST) on 07.04.2026 Technical Bid will be opened by the Bid Opening Committee on the same day at 1530 hours (IST) in the office of Central Electricity Authority, in the online presence of Bidders’ representatives who wish to attend. If the Bid Deadline is a public holiday at the place of submission of Bid, it shall be opened on the next working day at the same time and venue. In addition to the online submission, the Bidder with lowest Final Offer will be required to submit original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B before issuance of LoI. Bidders meeting the Qualification Requirements, subject to evaluation as specified in Clause 3.2 to 3.4 shall be declared as “Qualified Bidders” and eligible for opening of Initial Offer. 11. The RFP document is not transferable. BPC reserves the right to reject all Bids and/or annul the process of tariff based competitive bidding for selection of Bidder as TSP to execute the Project without assigning any reason. BPC shall not bear any liability, whatsoever, in this regard. REC Power Development and Consultancy Limited 8RFP for Selection of Bidder as Transmission Service Provider 12. Nodal person for enquiries and clarifications All correspondence and clarification in respect of RFP document shall be addressed to: Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Email: vijay.kulkarni@recpdcl.in& tbcb@recpdcl.in REC Power Development and Consultancy Limited 9RFP for Selection of Bidder as Transmission Service Provider DISCLAIMER 1. This Request for Proposal (RFP) document is not an agreement or offer by the BPC to the prospective Bidders or to any other party. The purpose of this RFP document is to provide interested parties with information to assist the formulation of their Bid. The RFP document is based on material and information available in public domain. 2. This RFP, along with its Annexure, is not transferable and the information contained therein are to be used only by the person to whom it is issued. It may not be copied or distributed by the recipient to third parties (other than in confidence to the recipient's professional advisors). In the event that the recipient does not continue with its involvement in the Project in accordance with this RFP, this RFP must be kept confidential. 3. While this RFP has been prepared in good faith, neither the BPC nor its employees or advisors/consultants make any representation or warranty expressed or implied as to the accuracy, reliability or completeness of the information contained in this RFP. The Bidders shall satisfy themselves, on receipt of the RFP document, that the RFP document is complete in all respects. Intimation of any discrepancy shall be given to this office immediately. If no intimation is received from any Bidder within ten (10) days from the date of issue of this RFP document on or before the date & time mentioned in this RFP, it shall be considered that the issued document, complete in all respects, has been received by the Bidders. This bidding process is in accordance with the Bidding Guidelines issued by Ministry of Power, Government of India under Section 63 of the Electricity Act, 2003. Revisions or amendments in these Bidding Guidelines may cause the BPC to modify, amend or supplement this RFP document, including the RFP Project Documents to be in conformance with the Bidding Guidelines. 4. This RFP document includes statements, which reflect various assumptions arrived at by BPC in order to give a reflection of current status in the RFP. These assumptions should not be entirely relied upon by Bidders in making their own assessments. This RFP document does not purport to contain all the information each Bidder may require and may not be appropriate for all persons. It is not possible for BPC to consider the investment objectives, financial situation and particular needs of each party who reads or uses this RFP document. Certain Bidders may have a better knowledge of the Project than the others. Each Bidder should conduct its own investigations and analysis and should check the accuracy, reliability and completeness of the information in this RFP document and obtain independent advice from appropriate sources. 5. Neither BPC nor their employees or consultants make any representation or warranty as to the accuracy, reliability or completeness of the information in this RFP document. 6. Neither BPC, its employees nor its consultants will have any liability to any Bidder or any other person under the law of contract, tort, the principles of restitution or unjust enrichment or otherwise for any loss, expense or damage which may arise from or be incurred or suffered in connection with anything contained in this RFP document, any matter deemed to form part of this RFP document, the award of the Project, the information supplied by or on behalf of BPC or its employees, any consultants or otherwise arising in any way from the qualification process for the said Project. 7. By participating in the bidding process, each of the Bidder shall have acknowledged and REC Power Development and Consultancy Limited 10RFP for Selection of Bidder as Transmission Service Provider accepted that it has not been induced to enter into such agreement by any representation or warranty, expressed or implied, or relied upon any such representation or warranty by or on behalf of BPC or any person working in the bidding process. 8. BPC may in its absolute discretion, but without being under any obligation to do so, update, amend or supplement this RFP document. Such updations, amendments or supplements, if any, will however be circulated to the Bidders not later than 15 days prior to the last date for submission of Bid. 9. Each Bidder unconditionally agrees, understands and accepts that the BPC reserves the rights to accept or reject any or all Bids without giving any reason. Neither the BPC nor its advisers shall entertain any claim of any nature, whatsoever, including without limitations, any claim seeking expenses in relation to the preparation of Bids. 10. This RFP may be withdrawn or cancelled by the BPC at any time without assigning any reasons thereof. BPC further reserves the right, at its complete discretion to reject any or all of the Bids without assigning any reasons whatsoever. REC Power Development and Consultancy Limited 11RFP for Selection of Bidder as Transmission Service Provider INDEX PAGE SECTION CONTENTS NO. Definitions 14 1. Introduction 19 2. Information And Instructions For Bidders 27 3. Evaluation Of The Technical And Financial Bid 54 4. Annexures For Bid 60 Annexures 1 Format for the Covering Letter 62 2 Format for Letter of Consent from Consortium Members 66 3 Format for evidence of authorized signatory’s authority (Power 68 of Attorney) 4 Format for Power of Attorney to be provided by each of the 70 other members of the Consortium in favor of the Lead Member 5 Format for Bidder’s composition and ownership structure and 72 & 74 Format for Authorization 6 Format for Consortium Agreement 75 7A Format for Qualification Requirement – Net worth 80 7B Format for Technical Requirement 83 7C Format for Technical and Financial Requirement – 86 Relationship & Equity Shareholding 7D Format for Additional Information for verification of Financial 88 and Technical Capabilities of Bidders 8 Format for Undertaking and Details of Equity Investment 91 9 Format for Authorization from Parent / Affiliate of Bidding 96 Company / Member of Bidding Consortium whose technical / financial capability has been used by the Bidding Company / Member of Bidding Consortium. 10 Format for Undertaking by Technically/Financially Evaluated 98 Entity/Ultimate Parent Company 11 Format for Board Resolution 100 11A Illustration for Applicable Board Resolution Requirements 103 under Clause 2.5.2 12 Format for illustration of Affiliates 105 13 Format for disclosure 106 14 Format For Bid Bond 107 14A Format of the Surety Bond for Bid Security 109 REC Power Development and Consultancy Limited 12RFP for Selection of Bidder as Transmission Service Provider PAGE SECTION CONTENTS NO. 14B Format of Payment on Order Instrument to be issued by 111 IREDA/REC/PFC 15 Format for Contract Performance Guarantee 114 15A Format for Surety Insurance Contract 117 15B Format for issuance of Payment on Order Instrument 119 16 Format for Checklist for Technical Bid Submission 122 Requirements 17 List of Banks 125 18 Grid Map of the Project 126 19 Format for Clarifications / Amendments on the RFP / RFP 127 Project Documents 20 Formats For RFP Project Documents 128 21 Format For Financial Bid 129 22 Format of Affidavit 130 Annexure A 132 Annexure-B 133 Annexure-C 140 REC Power Development and Consultancy Limited 13RFP for Selection of Bidder as Transmission Service Provider DEFINITIONS Any capitalized term, used but not defined in this RFP, shall have the meaning ascribed to such term in the RFP Project Documents, or the Bidding Guidelines, in that order. In absence of availability of definitions in the foregoing references, the capitalized terms shall be interpreted in accordance with the Electricity Act 2003, Grid Code or any other relevant electricity law, rule or regulation prevalent in India, as amended or re-enacted from time to time, in that order. The following terms are defined for use in this RFP: "Acquisition Price" shall have the same meaning as defined in the Share Purchase Agreement; “Affiliate” shall mean a company that either directly or indirectly i. controls or ii. is controlled by or iii. is under common control with a Bidding Company (in the case of a single company) or a Member (in the case of a Consortium) and “control” means ownership by one entity of at least twenty six percent (26%) of the voting rights of the entity. As an illustration a chart is annexed hereto as Annexure – 12; “Bid” shall mean Technical Bid and Financial Bid (Initial Offer and Final Offer) submitted by the Bidder, in response to this RFP, in accordance with the terms and conditions thereof; “Bidder” shall mean either a single company (including its permitted successors and legal assigns) or a Consortium of companies (including its permitted successors and legal assigns) submitting a Bid in response to this RFP. Any reference to the Bidder includes Bidding Company, Bidding Consortium/ Consortium, Member in a Bidding Consortium and Lead Member of the Bidding Consortium jointly and severally, as the context may require; “Bidding Company” shall refer to such single company (including its permitted successors and legal assigns) that has submitted a Bid for the Project; “Bidding Consortium/ Consortium” shall refer to a group of companies (including their permitted successors and legal assigns) that has collectively submitted a Bid for the Project; “Bidding Guidelines” shall mean the “Tariff Based Competitive-Bidding Guidelines for Transmission Service” and “Guidelines for Encouraging Competition in Development of Transmission Projects” issued by Government of India, Ministry of Power under Section – 63 of Electricity Act as amended from time to time; “Bid Bond” shall mean the unconditional and irrevocable bank guarantee or unconditional and irrevocable Insurance Surety Bond issued by Insurance Company authorized by Insurance Regulatory and Development Authority of India) or Payment on Order Instrument for Rupees Seventy-Eight Crore and Seventy Lakhs (Rs. 78.70 Crore) only, to be submitted along with the Technical Bid by the Bidder under Clause 2.11 of this RFP, as per the format prescribed in Annexure 14 (for Bank Guarantee) or Annexure 14A (for Insurance Surety Bond) or Annexure 14B (for Payment on Order); "Bid Deadline" shall mean the last date and time for submission of online Bid in response to REC Power Development and Consultancy Limited 14RFP for Selection of Bidder as Transmission Service Provider this RFP, specified in Clause 2.7.1; “Bid Process Coordinator or BPC” shall mean a person or its authorized representative as notified by the Government of India, responsible for carrying out the process for selection of Bidder who will acquire Transmission Service Provider; "CEA" shall mean the Central Electricity Authority constituted under Section - 70 of the Electricity Act; “Commission” or “CERC” shall mean the Central Electricity Regulatory Commission of India constituted under Section-76 of The Electricity Act, 2003 and any successors and assigns; “Conflict of Interest” A Bidder shall be considered to be in a Conflict of Interest with one or more Bidders in the same bidding process if they have a relationship with each other, directly or through a common company, that puts them in a position to have access to information about or influence the Bid of another Bidder. Provided that if two or more bidders in the bidding process have formed a Joint Venture Company or Consortium to execute another project, the Bidders will not be considered to have Conflict of Interest; "Commercial Operation Date (COD)" shall mean the date as per Article 6.2 of the Transmission Service Agreement; “Consents, Clearances, Permits” shall mean all authorizations, licenses, approvals, registrations, permits, waivers, privileges, acknowledgements, agreements, or concessions required to be obtained from or provided by any concerned authority for the development, execution and performance of Project including without any limitation on the construction, ownership, operation and maintenance of the transmission lines and/or sub-stations; "Contract Performance Guarantee" shall have the meaning as per Clause 2.12 of this RFP; "Contract Year" shall mean the period beginning on the Scheduled COD, and ending on the immediately succeeding March 31 and thereafter each period of 12 months beginning on April 1 and ending on March 31 provided that: (i) the last Contract Year shall end on the last day of the term of the Transmission Service Agreement; "CTU/Central Transmission Utility" shall have same meaning as defined in the Electricity Act, 2003; “Designated ISTS Customers” or “DICs” shall have the meaning as ascribed in Regulation 2(l) of Central Electricity Regulatory Commission (Sharing of inter-State Transmission Charges and Losses) Regulation 2020 and as amended or modified from time to time; "Effective Date" shall have the meaning as ascribed thereto in the Transmission Service Agreement; "Element" shall mean-each Transmission Line or each circuit of the Transmission Lines (where there are more than one circuit) or each bay of the Sub-station or switching station or HVDC REC Power Development and Consultancy Limited 15RFP for Selection of Bidder as Transmission Service Provider terminal or inverter station of the Project, including ICTs, Reactors, SVC, FSC, etc. forming part of the ISTS which will be owned, operated and maintained by the concerned ISTS Licensee, and which may have a separate scheduled COD as per Schedule 2 of the Transmission Service Agreement and may have a separate percentage for recovery of Transmission Charges on achieving COD as per Schedule 5 of the Transmission Service Agreement; “Final Offer” shall mean the Quoted Transmission Charges, required to be submitted as part of the Financial Bid on the electronic bidding platform during the e-reverse bidding stage. In case, no Final Offer is received during the e-reverse bidding stage then the lowest “Initial Offer” shall be deemed to be the Final Offer; “Financial Bid” shall mean the Initial Offer and Final Offer, containing the Bidder’s Quoted Transmission Charges, as per the format at Annexure – 21 of this RFP; “Financially Evaluated Entity” shall mean the company which has been evaluated for the satisfaction of the financial requirement set forth in Clause 2.1.3 hereof; “Government” shall mean the Central Government; “Grid Code” / “IEGC” or “State Grid Code” shall mean the Grid Code specified by the Central Commission under clause (h) of sub-section (1) of Section 79 of the Electricity Act and/or the State Grid Code as specified by the concerned State Commission referred under clause (h) of sub-section (1) of Section 86 of the Electricity Act as applicable; “Infrastructure sector” shall mean such sectors notified by Department of Economic Affairs in its Gazette Notification no. 13/1/2017-INF dated 14th November, 2017 and as amended from time to time; “Initial Offer” shall mean the Quoted Transmission Charges, required to be submitted as part of the Financial Bid on the electronic bidding platform along with the Technical Bid; “Inter State Generating Station” or “ISGS” shall mean a Central / other generating station in which two or more states have shares and whose scheduling is to be coordinated by the Regional Load Despatch Centre; “Inter-State Transmission System” shall have same meaning as defined in the Electricity Act, 2003; “Lead Member of the Bidding Consortium” or “Lead Member” shall mean a company who commits at least twenty six percent (26%) equity stake in the Project, meets the technical requirement as per Clause 2.1.2 and so designated by other Member(s) in Bidding Consortium; “Letter of Intent” or “LoI” shall mean the letter to be issued by the BPC to the Bidder, who has been identified as the selected bidder, for award of the Project to such Bidder; “Member in a Bidding Consortium/Member” shall mean each company in the Bidding Consortium; “MOP” shall mean the Ministry of Power, Government of India; "MOEF" shall mean the Ministry of the Environment and Forests, Government of India; REC Power Development and Consultancy Limited 16RFP for Selection of Bidder as Transmission Service Provider "National Committee on Transmission" shall mean the committee constituted by the Ministry of Power, Government of India in terms of the "Guidelines for Encouraging Competition in Development of Transmission Projects", as notified from time to time; “Nodal Agency” shall mean CTU, which shall execute and implement the Transmission Service Agreement (TSA); Provided that while taking major decisions, CTU shall consult CEA on technical matters and any other matter it feels necessary. “Parent Company” shall mean an entity that holds at least twenty six percent (26%) of the paid - up equity capital directly or indirectly in the Bidding Company or in the Member in a Bidding Consortium, as the case may be; "Payment on Order Instrument" shall mean Letter of Undertaking from Indian Renewable Energy Development Agency Limited (IREDA) or Power Finance Corporation Limited (PFC) or REC Limited (REC) [the three non-banking financial institutions under Ministry of New & Renewable Energy (MNRE)/ Ministry of Power (MoP)], to pay in case situation of default of Transmission Service Provider (TSP) in terms of tender conditions/ Power Purchase Agreement (PPA) arises. Such Letter(s) will have same effect as that of a Bank Guarantee issued by any public sector bank. Such "Payment on Order instrument" would have terms and conditions similar to that of any Bank Guarantee given by any public sector bank and would promise to pay the Nodal Agency on demand within stipulated time. TSPs can seek such Letter(s) by offering due security to the above-mentioned three nonbanking financial institutions mentioned above (IREDA, PFC & REC). Nodal Agency shall not accept the instrument of 'Letter of Undertaking' as described above or in any other form, from any other non-banking financial institutions or bank, except IREDA, PFC & REC. “Qualification Requirements” shall mean the qualification requirements as set forth in Section- 2, Clause 2.1 of this RFP; “Quoted Transmission Charges” shall mean the quoted single annual Transmission Charges submitted online through the electronic bidding platform by the Bidder as part of its Financial Bid as per the format in Annexure – 21 of this RFP; “RFP” shall mean Request for Proposal document along with all schedules, formats, annexure and RFP Project Documents attached hereto, issued by BPC for tariff based competitive bidding process for selection of bidder who will acquire the TSP through e-reverse bidding to execute the Project, and shall include any modifications, amendments or alterations or clarifications thereto; “RFP Project Documents” shall mean the following documents to be entered into in respect of the Project, by the parties to the respective agreements: a. Transmission Service Agreement (TSA), b. Share Purchase Agreement, c. Agreement(s) required, if any, under Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time and d. Any other agreement, as may be required; "Scheduled COD" shall have the meaning as ascribed hereto in Clause 2.6 of this RFP; REC Power Development and Consultancy Limited 17RFP for Selection of Bidder as Transmission Service Provider “Statutory Auditor” shall mean the auditor appointed under the provisions of the Companies Act, 1956 / Companies Act, 2013 (as the case may be) or under the provisions of any other applicable governing law; "Share Purchase Agreement" shall mean the agreement amongst REC Power Development and Consultancy Limited, ……………… (Insert the name of SPV) and the Successful Bidder for the purchase of one hundred (100%) per cent of the shareholding of the ……………… (Insert the name of SPV) for the Acquisition Price, by the Successful Bidder on the terms and conditions as contained therein; "Successful Bidder" or "Selected Bidder" shall mean the Bidder selected pursuant to this RFP to acquire one hundred percent (100%) equity shares of ……………… (Insert the name of SPV), along with all its related assets and liabilities, which will be responsible as the TSP to establish the Project on build, own, operate and transfer basis as per the terms of the Transmission Service Agreement and other RFP Project Documents; "Survey Report" shall mean the report containing initial information regarding the Project and other details provided as per the provisions of Clause 1.6.2.1.1 of this RFP; "Technical Bid" shall mean the bid submitted online through the electronic bidding platform, containing the documents as listed out in Clause 2.5.2 of this RFP; “Technically Evaluated Entity” shall mean the company which has been evaluated for the satisfaction of the technical requirement set forth in Clause 2.1.2 hereof; “Transmission Charges” shall mean the Final Offer quoted by Selected Bidder and adopted by the Commission, and as computed in terms of the provisions of Schedule 4 of the TSA, payable to the ISTS Licensee by the Designated ISTS Customers, and collected / disbursed by the CTU, as per Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time; “Transmission License” shall mean the license granted by the Commission in terms of the relevant regulations for grant of such license issued under the Electricity Act, 2003; “Transmission Service Agreement” or “TSA” shall mean the agreement entered into between Nodal Agency and the TSP, pursuant to which the TSP shall build, own, operate and transfer the Project and make available the assets of the Project on a commercial basis; “Transmission Service Provider” or “TSP” shall mean ……………… (Insert the name of SPV) which has executed the Transmission Service Agreement and which shall be acquired by the Selected Bidder; “Ultimate Parent Company” shall mean an entity which owns at least twenty six percent (26%) equity in the Bidding Company or Member of a Consortium, (as the case may be) and in the Technically Evaluated Entity and/or Financially Evaluated Entity (as the case may be) and such Bidding Company or Member of a Consortium, (as the case may be) and the Technically Evaluated Entity and/or Financially Evaluated Entity (as the case may be) shall be under the direct control or indirectly under the common control of such entity. REC Power Development and Consultancy Limited 18RFP for Selection of Bidder as Transmission Service Provider SECTION – 1 INTRODUCTION REC Power Development and Consultancy Limited 19RFP for Selection of Bidder as Transmission Service Provider SECTION 1 1. INTRODUCTION 1.1 Ministry of Power, Government of India vide its Gazette Notification No. 5827 [F. No. 15/3/2018-Trans-Part (4)] dated 26.12.2025 has notified REC Power Development and Consultancy Limited (RECPDCL) to be the Bid Process Coordinator (BPC) for the purpose of Selection of Bidder as Transmission Service Provider to establish Inter-State Transmission scheme for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process. The BPC hereby invites Bids from all prospective Bidders in accordance with this Request for Proposal (RFP) to select prospective Transmission Service Provider (TSP) in accordance with the “Tariff Based Competitive-Bidding Guidelines for Transmission Service” and “Guidelines for Encouraging Competition in Development of Transmission Projects” issued by Government of India, Ministry of Power under Section – 63 of the Electricity Act. The BPC shall select the Bidder having the prescribed technical and financial capability to become TSP and be responsible for establishing the Project in the state(s) of Andhra Pradesh & Telangana. The TSP will make the Project available against payment of Transmission Charges, as adopted by the Commission, payable to the TSP, as per Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time. 1.2 The TSP will be required to establish the following Inter State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” (hereinafter referred to as ‘Project’) on build, own, operate and transfer basis, and to provide transmission service. Scheduled COD in Sl. No. Scope of the Transmission Scheme months from Effective Date Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) GIS substation with 1x330 MVAr (765 kV) bus reactor with space provision for establishment of 220 kV switchyard  765/400 kV, 1500 MVA, ICTs – 4 Nos. (13x500 MVA incl. 1 spare unit) 1.  765 kV ICT bay – 4 Nos. 30 Months  400 kV ICT bay – 4 Nos.  765 kV line bays – 2 Nos. (at Pendurthi (Vizag) GIS for termination of Pendurthi (Vizag) – Srikakulam 765 kV D/c line)  765 kV line bays – 2 Nos. with provision of SLR (at Pendurthi (Vizag) GIS for termination of Khammam- II – Pendurthi (Vizag) –765 kV D/c line) REC Power Development and Consultancy Limited 20RFP for Selection of Bidder as Transmission Service Provider  765 kV, 330 MVAr Bus Reactors – 1 No. (4x110 MVAr inc. 1 switchable spare unit for both bus reactor and line reactor)  765 kV Bus Reactor bays – 1 No.  400 kV line bays – 4 Nos. (at Pendurthi (Vizag) GIS for termination of LILO of Kalpakka – Maradam 400 kV (quad) D/c line at Pendurthi) Future Space Provisions:  765/400 kV, 1500 MVA, ICTs – 2 Nos.  765 kV ICT bays – 2 Nos.  400 kV ICT bays – 2 Nos.  765 kV line bays – 8 Nos. (with provision for SLR)  400 kV line bays – 12 Nos. (with provision for SLR)  400 kV Bus Sectionalizer : 1 set Future Space Provisions for 220kV switchyard:  400/220 kV, 500 MVA, ICTs – 10 Nos.  400 kV ICT bays – 10 Nos.  220 kV ICT bays – 10 Nos.  220 kV line bays – 16 Nos.  220 kV Bus Sectionalizer: 3 set  220 kV Bus Coupler (BC) Bay – 4 Nos.  220 kV Transfer Bus Coupler (TBC) Bay – 4 Nos. + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS with control switching arrangement for proposed 1x330 MVAr bus reactor Space provision for 2nd + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS 2.  + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS with control switching arrangement for proposed 1x330 MVAr bus reactor – 1 set  400 kV bay – 1 No. Pendurthi (Vizag) – Srikakulam 765 kV D/c line with 330 MVAr SLR (convertible) at Srikakulam end on both 3. circuits REC Power Development and Consultancy Limited 21RFP for Selection of Bidder as Transmission Service Provider  765 kV line along with SLR GIS bays at Srikakulam - The D/c line to be terminated in the future line bays with SLR proposed under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid”  765 kV, 330 MVAr SLR at Srikakulam – 2 Nos. (7x110 MVAr switchable units inc. 1 switchable spare unit) LILO of Kalpakka – Maradam 400 kV (quad) D/c line at 4. Pendurthi Establishment of 3x1500 MVA, 765/400 kV Khammam- II substation with 1x330 MVAr (765 kV) bus reactor with space provision for establishment of 220 kV switchyard  765/400 kV, 1500 MVA, ICTs – 3 Nos. (10x500 MVA incl. 1 spare unit)  765 kV ICT bay – 3 Nos.  400 kV ICT bay – 3 Nos.  765 kV line bays – 4 Nos. (at Khammam-II for termination of Khammam-II – Pendurthi and Khammam-II – Warangal New 765 kV D/c lines)  765 kV, 330 MVAr Bus Reactors – 1 No. (4x110 MVAr inc. 1 switchable spare unit for both bus reactor and line reactor)  765 kV Bus Reactor bays – 1 No.  400 kV line bays – 2 Nos. (at Khammam-II for termination of Khammam-II – Khammam (existing) 5. 400 kV (quad) D/c line) Future Space Provisions:  765/400 kV, 1500 MVA, ICTs – 3 Nos.  765 kV ICT bays – 3 Nos.  400 kV ICT bays – 3 Nos.  765 kV line bays – 8 Nos. (with provision for SLR)  400 kV line bays – 10 Nos. (with provision for SLR)  400 kV Bus Sectionalizer: 1 set Future Space Provisions for 220kV switchyard:  400/220 kV, 500 MVA, ICTs – 10 Nos.  400 kV ICT bays – 10 Nos.  220 kV ICT bays – 10 Nos.  220 kV line bays – 16 Nos.  220 kV Bus Sectionalizer: 3 set  220 kV Bus Coupler (BC) Bay – 4 Nos. REC Power Development and Consultancy Limited 22RFP for Selection of Bidder as Transmission Service Provider  220 kV Transfer Bus Coupler (TBC) Bay – 4 Nos Khammam-II – Warangal New 765 kV D/c line 6.  765 kV line bays – 2 Nos. (at Warangal New) Khammam-II – Pendurthi (Vizag) 765 kV D/c line with 330 MVAr SLR (convertible) at both ends on both circuits  765 kV, 330 MVAr SLR at Pendurthi(Vizag) – 2 Nos. (6x110 MVAr switchable units) 7.  Switching Equipment for 765 kV SLR at Pendurthi (Vizag) GIS – 2 Nos  765 kV, 330 MVAr SLR at Khammam-II – 2 Nos. (6x110 MVAr switchable units)  Switching Equipment for 765 kV SLR at Khammam- II PS – 2 Nos Khammam-II – Khammam (existing) 400 kV (quad) D/c line 8.  400kV line bays – 2 Nos. (at Khammam (existing)) Note: i. Bay(s) required for completion of diameter (GIS) in one-and-half breaker scheme shall also be executed by the TSP. ii. POWERGRID to provide space (free of cost) for 765 kV line along with SLR GIS bays at Srikakulam - The D/c line to be terminated in the future line bays with SLR proposed under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid” iii. POWERGRID to provide space (free of cost) for 2 Nos. of 400 kV line bays at Khammam for termination of Khammam-II – Khammam (existing) 400 kV (quad) D/c line iv. TSP of Warangal New S/s (Adani) to provide space (free of cost) for 2 Nos. of 765 kV line bays with provision of SLR at Warangal New S/s for termination of Khammam-II – Warangal New 765 kV D/c line 1.3 Project Description As per the Communication from MNRE, about 5000 MW demand at Vizag area and 6000 MW at Kakinada area has been envisaged for the Green Hydrogen / Green Ammonia projects. The transmission system for proposed Green Hydrogen / Green Ammonia projects in Kakinada area, Andhra Pradesh (Phase-I) is presently under bidding. Further, a comprehensive Transmission system for Green Hydrogen / Green Ammonia projects at Kakinada (Ph-II) and Pendurthi have been identified. REC Power Development and Consultancy Limited 23RFP for Selection of Bidder as Transmission Service Provider Further, a number of datacentre loads are envisaged near Pendurthi / Vizag area and applications have already been received from certain developers at Pendurthi by APTRANSCO for which the subject transmission system shall be used. The Transmission System was discussed and agreed in the 38th CMETS-SR held on 02.06.2025. The scheme was further discussed and agreed in the 55th SRPC meeting held on 26.07.2025. Further, CTU have received GNA application for 2500 MW as bulk consumer from different Green Hydrogen / Green Ammonia project developer. The present transmission scheme shall facilitate integration and supply of power to Green Hydrogen / Green Ammonia projects for meeting their demand for about 4500 MW. The National Committee on Transmission in its 32nd meeting held on 12.08.2025 has recommended the implementation of the subject transmission scheme through TBCB route and has identified the RECPDCL as BPC for bidding of the transmission scheme. Ministry of Power vide Gazette notification dated 26.12.2025 has notified the transmission scheme for implementation through TBCB route. 1.4 Transmission Grid Map Transmission Grid Map indicating the location of the Project is enclosed as Annexure 18 of this RFP for information and reference of the Bidders. 1.5 The objective of the bidding process is to select a Successful Bidder pursuant to this RFP, who shall acquire one hundred percent (100%) of the equity shares of ……………… (Insert the name of SPV) along with all its related assets and liabilities as per the provisions of the Share Purchase Agreement, at the Acquisition Price to be intimated by the BPC, twenty (20) days prior to the Bid Deadline. 1.6 The ……………… (Insert the name of SPV), of which one hundred percent (100%) equity shares will be acquired by the Selected Bidder, shall be responsible as the TSP, for ensuring that it undertakes ownership, financing, development, design, engineering, procurement, construction, commissioning, operation and maintenance of the Project, and to provide Transmission Service as per the terms of the RFP Project Documents. The TSP shall ensure transfer of all project assets along with substation land, right of way and clearances to CTU or its successors or an agency as decided by the Central Government after 35 years from COD of project at zero cost and free from any encumbrance and liability. The transfer shall be completed within 90 days after 35 years from COD of project failing which CTU shall be entitled to take over the project assets Suo moto. 1.7 Brief Scope of Work 1.6.1 Scope of Transmission Service Provider The TSP’s scope of work for the Project shall comprise, but not necessarily be limited to the following: REC Power Development and Consultancy Limited 24RFP for Selection of Bidder as Transmission Service Provider 1.6.1.1 Establishment, operation and maintenance of the Project on build, own, operate and transfer basis and completion of all the activities for the Project, including survey, detailed project report formulation, arranging finance, project management, necessary Consents, Clearances and Permits (way leave, environment & forest, civil aviation, railway/ road/river/canal/power crossing/PTCC, etc.), land compensation, design, engineering, equipment, material, construction, erection, testing & commissioning. Further, the actual location of Greenfield Substation (Switching Station or HVDC Terminal or Inverter Station) in the scope of TSP: • For a Generation Pooling Substation shall not be beyond 3 Km radius of the location proposed by the BPC in their Survey Report. • For Load Serving Substation within the scope of TSP shall not be beyond 5 Km radius of the location proposed by the BPC in their Survey Report. • For an Intermediate Substation shall not be beyond 10 Km radius of the location proposed by the BPC in their Survey Report. 1.6.1.2 The TSP shall ensure that design, construction and testing of all equipment, facilities, components and systems of the Project shall be in accordance with Transmission Service Agreement and applicable Rules/ Regulations, Orders and Guidelines issued by the Central Government. 1.6.1.3 The TSP shall ensure timely completion of entire scope of Project in all respects and its operation and maintenance, as shall be specified in the RFP documents. 1.6.1.4 The TSP shall seek Transmission License from the Commission, as per the provisions of the Electricity Act and regulations made thereunder. 1.6.1.5 The TSP shall seek approval under Section 164 of Electricity Act, from CEA after acquisition of ……………… (Insert the name of SPV). The approval shall be granted by CEA generally within 30 days but in no case later than 45 days from the date of receipt of application (complete in all aspects). 1.6.2 Scope of Bid Process Coordinator (BPC) BPC’s scope of work is briefly outlined hereunder: 1.6.2.1 The BPC has initiated development of the Project and shall be responsible for the tasks in this regard as specified hereunder: 1. Provide to the Bidders a Survey Report for the Project at least forty five (45) days prior to the Bid Deadline. The Survey Report shall include the suggested route with approximate route length, type of terrain likely to be encountered and its likely implication in terms of Right of Way (ROW), statutory clearances, location of substations or converter stations and land area to be acquired for the substation or converter station. 2. To obtain approval for laying of overhead transmission lines under Section 68 of Electricity Act, from the Government at least twenty (20) days prior to Bid Deadline. REC Power Development and Consultancy Limited 25RFP for Selection of Bidder as Transmission Service Provider 3. To initiate acquisition of land for location specific substations, switching stations or HVDC terminal or inverter stations, if required. 4. To initiate process of seeking forest clearance, if required 5. The BPC shall intimate to the Bidders, the Acquisition Price payable by the Selected Bidder to the REC Power Development and Consultancy Limited for the acquisition of one hundred percent (100%) of the equity shareholding of ……………… (Insert the name of SPV), along with all its related assets and liabilities at least twenty (20) days prior to the Bid Deadline. 6. The BPC shall ensure issuance of all finalized RFP Project Documents, at least fifteen (15) days prior to the Bid Deadline. Provided that for any delay in meeting the above obligations of the BPC within the specified time period above, the Bid Deadline as per Clause 2.7.1 shall be extended on a day for day basis. 1.6.2.2 The details and documents as may be obtained by the BPC/ project specific SPV in relation to the Project shall be handed over to the TSP on an as-is-where-is basis, so that it may take further actions to obtain Consents, Clearances and Permits. 1.7 All costs (including direct and indirect) incurred by the BPC/ project specific SPV in connection with the activities concerning the Project shall be recovered from the TSP, which shall be included in the Acquisition Price. 1.8 The Project is required to be completed progressively in accordance with the schedule prescribed in this RFP. 1.9 A company under the Companies Act, 2013 by the name ……………… (Insert the name of SPV) has been incorporated to initiate the activities for execution of the Project. The said company shall be acquired by the successful Bidder as per terms and conditions as may be prescribed in RFP. 1.10 The Ministry of Power and the appropriate state government(s) shall provide their support to the TSP, on best endeavor basis, in enabling the TSP to develop the Project. 1.11 All Bidders are required to submit their Bid in accordance with the instructions set forth in this RFP. 1.12 Once the Successful Bidder is selected, the details and documents as may be obtained by the BPC/ project specific SPV in relation to the Project, shall be handed over to the Successful Bidder on as is where basis, so that it may take further actions to obtain all necessary Consents, Clearances and Permits and the TSP shall not be entitled for any extensions in the Scheduled COD of the Project except as provided for in the TSA. 1.13 The assets of the Project shall be made available on a commercial basis as per the terms and conditions of the Transmission Service Agreement and Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time. REC Power Development and Consultancy Limited 26RFP for Selection of Bidder as Transmission Service Provider SECTION - 2 INFORMATION AND INSTRUCTIONS FOR BIDDERS REC Power Development and Consultancy Limited 27RFP for Selection of Bidder as Transmission Service Provider SECTION – 2 2. INFORMATION AND INSTRUCTIONS FOR BIDDERS 2.1 Qualification Requirements 2.1.1 The Bidder should be a company duly incorporated under the relevant laws (Bidding Company) or a Consortium of companies (Bidding Consortium) with one of the companies acting as the Lead Member of the Bidding Consortium. The Bidder shall be selected on meeting the Qualification Requirements specified in Section 2 of this RFP, as demonstrated by the Bidder’s Technical Bid and the lowest Quoted Transmission Charges discovered from Final Offers quoted during the e-reverse bidding. A Bidding Consortium can participate in the bidding process for the Project if any Member of the Consortium has purchased the RFP document for such Project. Bidder who agree and undertake to procure the products associated with the Transmission System as per provisions of Public Procurement (Preference to Make in India) orders issued by Ministry of Power vide orders No. 11/5/2018 - Coord. dated 28.07.2020 as amended vide order No. A1/2021- FSC- Part(5) dated 16.11.2021 and No.: P45021/2/2017-PP (BE-II)-Part-4 Vol.II dated 19.07.2024 issued by Ministry of Power for transmission sector, as may be further amended from time to time, read with Department for Promotion of Industry and Internal Trade (DPIIT) orders in this regard, shall be eligible hereunder. Further, it is clarified that Procuring Entity as defined in orders shall deemed to have included Selected Bidder and/ or TSP. Besides, Department of Expenditure, Ministry of Finance in suppression of OMs issued vide Order (Public Procurement No 1) bearing File No. 6/18/2019-PPD dated 23.07.2020, Order (Public Procurement No 2) bearing File No. 6/18/2019-PPD dated 23.07.2020 and Order (Public Procurement No. 3) bearing File No. 6/18/2019-PPD, dated 24.07.2020, Office Memorandum (OM) No. F.18/37/2020-PPD dated 08.02.2021, OM No. F.12/1/2021- PPD(Pt.) dated 02.03.2021, OM No. F.7/10/2021-PPD dated 08.06.2021 and Order (Public Procurement No 4) bearing File No. F.7/10/2021-PPD dated 23.02.2023 as amended from time to time, have issued directions regarding public procurement from a bidder of a country, which shares land border with India are also applicable. 2.1.2 Technical requirement to be met by the Bidding Company or Lead Member of Bidding Consortium The Bidder must fulfill any one of the following technical requirements: (i) Experience of development of projects in the Infrastructure Sector in the last five (5) years with aggregate capital expenditure of not less than Rs. 3,935 Crore or equivalent USD (calculated as per provisions in Clause 3.4.1). However, the capital expenditure of each project shall not be less than Rs. 787 Crore or equivalent USD (calculated as per provisions in Clause 3.4.1). For this purpose, capital expenditure incurred on projects that have been commissioned/completed at least seven (7) days prior to Bid Deadline shall be considered. The capital expenditure discussed above shall be as capitalized and reflected in the audited books of accounts of the Technically Evaluated Entity. In case a clearly identifiable part of a project has been put into commercial operation, REC Power Development and Consultancy Limited 28RFP for Selection of Bidder as Transmission Service Provider the capital expenditure on such part of the project shall be considered. The Technically Evaluated Entity must have either executed such projects itself or must have held directly or indirectly at least twenty six percent (26%) of the shareholding in the company that has executed the project(s) from the date of financial closure of the project(s) till the time of commissioning/completion of such project(s). OR (ii) Experience in construction of project in infrastructure sector: The Technically Evaluated Entity should have received aggregate payments not less than Rs. 3,935 Crore or equivalent USD (calculated as per provisions in Clause 3.4.1) from its client(s) for construction works fully completed during the last 5(five) financial years. However, the payment received from each project shall not be less than Rs. 787 Crore or equivalent USD (calculated as per provisions in Clause 3.4.1). For this purpose, payments received on projects that have been commissioned/ completed at least seven (7) days prior to Bid Deadline shall be considered. Further only the payments (gross) actually received, during such 5 (five) financial years shall qualify for purposes of computing the technical capacity. For the avoidance of doubt, construction works shall not include cost of land, supply of goods or equipment except when such goods or equipment form part of a turn-key construction contract/ EPC contract for the project. Further, in cases where different individual contracts are signed between same entities for the same project, the cumulative payments received under such individual contracts shall be considered for meeting the qualification requirement. The Technically Evaluated Entity may be the Bidding Company or the Lead Member of a Consortium or an Affiliate or Parent of such Bidding Company or the Lead Member, as the case may be. Bidders shall furnish documentary evidence duly certified by authorized signatory of the Bidder who has been issued Power of Attorney in support of their technical capability as defined in Clause 2.1.2 of this RFP. 2.1.3 Financial requirement to be met by the Bidding Company/Bidding Consortium 2.1.3.1 The Bidder must fulfill following financial requirements: A. Networth: Networth should be not less than Rs. 1,574 Crore or equivalent USD (calculated as per provisions in Clause 3.4.1) computed as the Networth based on unconsolidated audited annual accounts (refer to Note below) of any of the last three (3) financial years as provided in Clause 2.2.3, immediately preceding the Bid Deadline. Also, the Networth of any of the last three (3) financial years should not be negative. Note: Audited consolidated annual accounts of the Bidder may be used for the purpose of financial criteria provided the Bidder has at least 26% equity in each company whose accounts are merged in the audited consolidated accounts and provided further that the financial capability of such companies (of which accounts are being merged in the consolidated accounts) shall not be considered again for the purpose of evaluation of the REC Power Development and Consultancy Limited 29RFP for Selection of Bidder as Transmission Service Provider Technical Bid. Bidders shall furnish prescribed Annexure 7 (A) duly certified by authorized signatory of the Bidder who has been issued Power of Attorney and the Statutory Auditor and separate computation sheet for Networth duly certified by Statutory Auditor in support of their financial capability as defined in Clause 2.1.3 of this RFP. 2.1.3.2 The Networth shall be computed in the following manner by the Bidder: A. Networth = Equity share capital Add: Reserves Subtract: Revaluation Reserves Subtract: Intangible Assets Subtract: Miscellaneous expenditures to the extent not written off and carry forward losses 2.1.3.3 If the Technical Bid is submitted by a Bidding Consortium the financial requirement shall be met individually and collectively by all the Members in the Bidding Consortium. The financial requirement to be met by each Member of the Bidding Consortium shall be computed in proportion to the equity commitment made by each of them for investment in the Project. 2.1.4 The Bidder may seek qualification on the basis of technical and financial capability of its Parent and/ or its Affiliate(s) for the purpose of meeting the Qualification Requirements. However, in the case of the Bidder being a Consortium, the Lead Member has to meet the technical requirement on its own or by seeking the technical capability of its Parent and/or its Affiliate(s). Authorization for use of such technical or financial capability shall have to be provided from its Parent and/or Affiliate(s) as per Annexure 9. The technical and financial capability of a particular company/ particular project, including its Parents and/or Affiliates, shall not be used directly or indirectly by more than one Bidder/ Member of a Bidding Consortium/ Bidding Company. However, development and construction experience of a particular project may be used by more than one company. The determination of the relationship of Parent or Affiliate with the Bidding Company or with the Member of the Bidding Consortium, including the Lead Member, shall be on the date at the most seven (7) days prior to the last date of submission of the Bid. Documentary evidence to establish such relationship shall be furnished by the Bidder along with the Technical Bid. If the Technically Evaluated Entity and/or Financially Evaluated Entity is an entity other than the Bidding Company or a Member in a Bidding Consortium, the Bidding Company or Member relying on such Technically Evaluated Entity and/or Financially Evaluated Entity will have to submit a legally binding undertaking supported by a board resolution from the Technically Evaluated Entity and/or Financially Evaluated Entity or its Ultimate Parent Company, that all the equity investment obligations of the Bidding Company or the Member of the Consortium shall be deemed to be equity investment obligations of the Technically Evaluated Entity and/or Financially Evaluated Entity or its Ultimate Parent Company, and in the event of any default the same shall be met by such evaluated entity or by or the Ultimate Parent Company. The Bidding Company or the Consortium Member shall have to provide information and documents relating to its relationship with such REC Power Development and Consultancy Limited 30RFP for Selection of Bidder as Transmission Service Provider Technically Evaluated Entity and/or Financially Evaluated Entity including details about the equity shareholding between them as per Annexure 7(C). 2.1.5 A Bidder shall submit only one Bid in the same bidding process, either individually as Bidding Company or as a Member of a Bidding Consortium (including the Lead Member). It is further clarified that any of the Parent/ Affiliate/Ultimate Parent of the Bidder/ Member in a Bidding Consortium shall not separately participate directly or indirectly in the same bidding process. Further, if any Bidder is having a Conflict of Interest with other Bidders participating in the same bidding process, the Bids of all such Bidders shall be rejected. 2.1.6 Notwithstanding anything stated above, BPC reserves the right to verify the authenticity of the documents submitted for meeting the Qualification Requirements and request for any additional information and documents. BPC reserves the right at its sole discretion to contact the Bidder’s bank and project references and verify the Bidder’s information and documents for the purpose of bid evaluation. 2.1.7 The Qualified Bidder(s) will be required to continue to maintain compliance with the Qualification Requirements throughout the bidding process and till execution of the Transmission Service Agreement. Where the Technically Evaluated Entity and/or the Financially Evaluated Entity is not the Bidding Company or a Member in a Bidding Consortium, as the case may be, the Bidding Company or Member shall continue to be an Affiliate of the Technically Evaluated Entity and/or Financially Evaluated Entity till the execution of the Transmission Service Agreement. Failure to comply with the aforesaid provisions shall make the Bid liable for rejection at any stage. 2.1.8 The Selected Bidder will be required to continue to maintain compliance with the Qualification Requirements till the COD of the Project. Where the Technically Evaluated Entity and/or the Financially Evaluated Entity is not the Bidding Company or a Member in a Bidding Consortium, as the case may be, the Bidding Company or Member shall continue to be an Affiliate of the Technically Evaluated Entity and/or Financially Evaluated Entity till the COD of the Project. Failure to comply with the aforesaid provisions shall be dealt as per provisions of Transmission Service Agreement. 2.1.9 On the Bid Deadline, for the Bidder to be eligible to participate in the bidding process: a. the Bidder & any of its Affiliate including any Consortium Member & any of its Affiliate, their directors or key personnel should not have been barred or included in the blacklist by any government agency or authority in India, the government of the jurisdiction of the Bidder or Members where they are incorporated or the jurisdiction of their principal place of business, any international financial institution such as the World Bank Group, Asian Development Bank, African Development Bank, Inter- American Development Bank, Asian Infrastructure Investment Bank etc or the United Nations or any of its agencies; or b. the Bidder & any of its Affiliate including any Consortium Member & any of its Affiliate or their directors should not have been convicted of any offence in India or abroad. In case any investigation is pending against the Bidder, including any Consortium Member or Affiliate, or CEO or any of the directors/ manager/key managerial personnel REC Power Development and Consultancy Limited 31RFP for Selection of Bidder as Transmission Service Provider of the Bidder /Consortium /Member or their Affiliates, full details of such investigation including the name of the investigating agency, the charge/offence for which the investigation has been launched, name and designation of persons against whom the investigation has been launched and other relevant information should be disclosed while submitting the Bid. The Bidders shall confirm the above though a notarized affidavit as per Annexure 22. 2.2 Submission of Bid by the Bidder 2.2.1 The information and documents in Technical Bid will be submitted by the Bidder as per the formats specified in Section – 4 (Formats for RFP) of this document 2.2.2 Strict adherence to the formats wherever specified, is required. Wherever, information has been sought in specified formats, the Bidder shall refrain from referring to brochures/ pamphlets. Non-adherence to formats and/ or submission of incomplete information may be a ground for declaring the Technical Bid as non-responsive. Each format has to be duly signed and stamped by the authorized signatory of Bidder. 2.2.3 The Technical Bid shall contain unconsolidated/consolidated audited annual accounts (consisting of unabridged Balance Sheet, Profit and Loss Account, profit appropriation account, Auditors Report, etc.), as the case may be, of Bidding Company or each Member in Consortium including Lead Member or the Financially Evaluated Entity for the last three (3) financial years immediately preceding the last date for submission of Bid for the purpose of calculation of Networth. In case the annual accounts for the financial year immediately preceding the Bid Deadline is not audited, the Bidder shall give declaration in this regard duly certified by its statutory auditor. In such a case, the Bidder shall provide the audited annual accounts for the three (3) financial years preceding the financial year as above for which the annual accounts have not been audited. 2.2.4 Bid submitted by a Bidding Consortium: 2.2.4.1 The Technical Bid shall contain a legally enforceable Consortium Agreement entered amongst the Members in the Bidding Consortium, designating one of the Members to be the Lead Member (as per Annexure 6). There shall be only one Lead Member which shall continue to hold twenty six percent (26%) equity in the TSP and cannot be changed upto one (1) year from the Commercial Operation Date (COD) of the Project. Each Member in Bidding Consortium shall duly sign the Consortium Agreement making it liable for raising the required funds for its respective equity investment commitment as specified in the Consortium Agreement. In absence of Consortium Agreement, the Technical Bid will not be considered for evaluation and will be rejected. Provided that the Lead Member of the Bidding Consortium will be required to be liable to the extent of 100% of the total proposed commitment of equity investment of the Bidding Consortium i.e. for both its own equity contribution as well as the equity contribution of other Members. Provided further that the Consortium Agreement shall not be amended without the explicit approval of the BPC. REC Power Development and Consultancy Limited 32RFP for Selection of Bidder as Transmission Service Provider The Lead Member of the Consortium will be the single point of contact for the purposes of the bid process before the date of signing of Share Purchase Agreement. Settlement of any dispute amongst the Consortium Members shall not be the responsibility of the BPC and/or the CTU and the BPC and/or the CTU shall not bear any liability whatsoever on this account. 2.2.4.2 The Lead Member should designate at the most two persons to represent the Consortium in its dealings with the BPC. The person(s) designated by the Lead Member should be authorized through a Power of Attorney (as per Annexure 3) to perform all tasks including, but not limited to providing information, responding to enquiries, signing of Technical Bid on behalf of the Consortium, etc. The Bidding Consortium shall provide board resolutions from their respective Boards for committing their respective portion of equity requirement for the Project. Additionally, the Lead member shall provide a Board resolution committing to make good any shortfall in the equity for the project, in case of any member not meeting its equity commitment. 2.2.4.3 The Technical Bid should also contain signed Letter of Consent (as per Annexure 2) from each Member in Consortium confirming that the entire Technical and Financial Bids has been reviewed and each element of the Technical and Financial Bids is agreed to by them including investment commitment for the Project. In addition, the Technical Bid should also contain Board Resolution from each Member of the Consortium other than the Lead Member in favour of their respective authorized representatives for executing the POA, Consortium Agreement and signing of the requisite formats. 2.2.5 Bid submitted by a Bidding Company 2.2.5.1 The Bidding Company should designate at the most two persons to represent the Bidding Company in its dealings with BPC. The person(s) should be authorized to perform all tasks including, but not limited to providing information, responding to enquiries, signing of Technical and Financial Bids etc. The Bidding Company should submit, along with Technical Bid, a Power of Attorney (as per Annexure 3), authorizing the signatory of the Technical and Financial Bids. The Bidding Company shall submit the board resolution committing 100% of equity requirement for the Project, in the Technical Bid. 2.3 Clarifications & Pre-Bid Meeting 2.3.1 The Bidders may seek clarifications or suggest amendments to the RFP by sending an email to the BPC at the email id indicated in Clause 2.14 within the date and time mentioned in Clause 2.7.2. For any such clarifications or amendments, the Bidders should adhere to the format as per Annexure – 19. 2.3.2 Only those Bidders or their authorized representatives, who have purchased the RFP documents are invited to attend the pre-bid meeting(s), which will take place on date as specified in Clause 2.7.2, or any such other date as notified by the BPC. The time and address of this would be intimated later. 2.3.3 The purpose of the pre-bid meeting will be to clarify any issues regarding the RFP, including in particular, issues raised in writing by the Bidders as per the provisions of REC Power Development and Consultancy Limited 33RFP for Selection of Bidder as Transmission Service Provider Clause 2.3.1. 2.3.4 Non-attendance at the pre-bid meeting will not be a cause for disqualification of a Bidder. 2.3.5 The BPC is not under any obligation to entertain / respond to suggestions made or to incorporate modifications sought for. 2.3.6 In case Bidders need any further clarifications not involving any amendments in respect of final RFP, they should ensure that request for such clarification is submitted through e- mail to the BPC at least ten (10) days prior to the Bid Deadline as mentioned in Clause 2.7.1. The BPC may issue clarifications only, as per its sole discretion, which is considered reasonable by it. Any such clarification issued shall be sent to all the Bidders to whom the RFP has been issued. Clarifications sought after this date shall not be considered in any manner and shall be deemed not to have been received. There shall be no extension in Bid Deadline on account of clarifications sought as per this clause 2.3.6. 2.4 Amendment of RFP 2.4.1. At any time before the timeline mentioned in Clause 2.7.1, the BPC may, for any reason, whether at its own initiative or in response to clarifications requested by any Bidder modify or amend the RFP, including the timelines specified in Clause 2.7.2 by issuance of addendum/modification/errata and/or revised document. Such document shall be notified in writing through a letter or fax or e-mail to all the entities to which the RFP has been issued and shall be binding on them. In order to ensure that Bidders have reasonable time to take the modification into account in preparing their Bid, or for any other reasons, BPC may at its discretion, extend the due date for submission of Bid. Late receipt of any addendum/modification/errata and/or revised document will not relieve the Bidder from being bound by that modification. 2.4.2. All modifications shall become part of the terms and conditions of this RFP. No interpretation, revision or communication regarding this RFP is valid, unless made in writing. 2.4.3. The amendment to the RFP shall be notified to all the Bidders through the electronic bidding platform and shall be binding on them. 2.5 The Bidding Process The entire bidding process shall be conducted on electronic bidding platform created by MSTC Limited. The Bid shall comprise of the Technical Bid and the Financial Bid. The Bidders shall submit the Technical Bid & Financial Bid through the electronic bidding platform. In addition to the online submission, the Bidder with lowest Final Offer will be required to submit original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B before issuance of LoI. There shall be no physical submission of the Financial Bid. Evaluation of Technical Bid will be carried out considering the information and documents furnished by the Bidders as required under this RFP. This step would involve responsiveness check, technical and financial evaluation of the details/ documents furnished by the Bidding Company / Bidding Consortium in support of meeting the Qualification Requirements. Bidders meeting the Qualification Requirements, subject to REC Power Development and Consultancy Limited 34RFP for Selection of Bidder as Transmission Service Provider evaluation as specified in Clause 3.2 to 3.4 shall be declared as “Qualified Bidders” and eligible for opening of Initial Offer. The BPC shall also upload the list of all Qualified Bidders and Non-Qualified Bidders on the bidding portal along with the reasons for non- qualification. Also, the Financial Bids of Qualified Bidders shall be opened after at least 24 hours from the date of declaration of the Technically Qualified Bidders. The Financial Bid will comprise of two rounds. In the first round the Initial Offer (submitted online along with the Technical Bids) of the responsive bids would be opened and Quoted Transmission Charges of Initial Offer shall be ranked on the basis of ascending order for determination of the Qualified Bidders as provided in Section-III of RFP. The Qualified Bidders, in the first fifty per cent of the ranking (with any fraction rounded off to higher integer) or four Qualified Bidders, whichever is higher, shall qualify for participating in the electronic reverse auction stage and submit their Final Offer. Provided however, in case only one Bidder remains after the evaluation of Technical Bid as per Clause 3.2, 3.3 and Clause 3.4, the Initial Offer of such Bidder shall not be opened and the matter shall be referred to the Government. Provided that in the event the number of qualified Technical Bids is between two and four, then each of the qualified Bidder shall be considered as “Qualified Bidders”. Provided that in the event of identical Quoted Transmission Charges discovered from the Initial Offer having been submitted by one or more Bidders, all such Bidders shall be assigned the same rank for the purposes of determination of Qualified Bidders. In such cases, all the Qualified Bidders who share the same rank till 50% of the rank (with any fraction rounded off to higher integer) determined above, shall qualify to participate in the electronic e-reverse auction stage. In case 50% of the ranks (with any fraction rounded off to higher integer) is having less than 4 (four) Bidders and the rank of the fourth (4th) Bidder is shared by more than one (1) Bidder, then all such Bidders who share the rank of the fourth (4th) Bidder shall qualify to participate in the electronic reverse auction. The applicable ceiling for electronic reverse bidding shall be the lowest Quoted Transmission Charges discovered from the Initial Offer received from the Qualified Bidders. The Qualified Bidders shall be permitted to place their Final Offer on the electronic bidding platform, which is lower than zero point two five (0.25) % of the prevailing lowest Quoted Transmission Charges. The initial period for conducting the e-reverse bidding should be 2 hours which will be extended by 30 minutes from the last received bid time, if the bid is received during the last 30 minutes of the scheduled or extended bid time. Subsequently, it will be extended again by 30 minutes from the latest received bid time. The technical details with respect to access to such electronic platform are provided in Annexure-A (Technical Details with respect to electronic reverse auction). In case of any technical clarification regarding access to the electronic reverse auction platform or conduct of the auction process, the Bidders may contact MSTC Limited directly at the address provided in Annexure-A. 2.5.1 Bid Formats REC Power Development and Consultancy Limited 35RFP for Selection of Bidder as Transmission Service Provider The Bids in response to this RFP will be submitted online through the electronic bidding platform by the Bidders in the manner provided in Clause 2.9. The Bids shall comprise of the following: 2.5.2 Technical Bid comprising of: 1. Covering Letter (as per prescribed format enclosed as Annexure 1); 2. Letter of Consent from Consortium Members in Annexure 2; 3. Power of attorney issued by the Bidding Company or the Lead Member of the Consortium, as the case may be, in favour of the person signing the Bid, in the format attached hereto as Annexure 3. Additionally, in case of a Bidding Consortium, the power of attorney in favour of the Lead Member issued by the other Members of the Consortium shall be provided in as per format attached hereto as Annexure 4. Further, the Lead Member shall furnish Board resolution(s) from each Member of the Consortium other than the Lead Member in favour of their respective authorized representatives for executing the POA and signing of the requisite formats. Provided that in the event the Bidding Company or the Lead Member of the Consortium or any Member of the Bidding Consortium, as the case may be, is a foreign entity, it may issue Board resolutions in place of power of attorney for the purpose of fulfilling these requirements. 4. Bidder’s composition and ownership structure in Annexure 5 5. Format for Authorization submitted in Non-Judicial stamp paper duly notarized as per Annexure 5 from the Bidding Company / each Member of the Consortium authorizing the BPC to seek reference from their respective bankers & others. 6. In case of Bidding Consortium, the Consortium Agreement shall be provided in as per format attached hereto as Annexure 6 7. Format of Qualification Requirement (Annexures 7A, 7B, 7C and 7D) 8. Bidders Undertakings and details of equity investment in Project (as per prescribed formats 1 and 2 of Annexure 8); 9. Authorization from Parent / Affiliate of Bidding Company / Member of Bidding Consortium whose technical / financial capability has been used by the Bidding Company / Member of Bidding Consortium (Annexure 9). 10. Undertaking from the Technically / Financially Evaluated Entity(ies) OR Undertaking from the Ultimate Parent Company, for total equity investment commitment, in the prescribed format in Annexure – 10, to meet any shortfall in the equity investment by the Selected Bidder in the ……………… (Insert the name of SPV). Note: The effective Equity holding of the Selected Bidder in the ……………… REC Power Development and Consultancy Limited 36RFP for Selection of Bidder as Transmission Service Provider (Insert the name of SPV), as specified in Clause 2.5.8.1 shall be computed as per the provisions of Clause 2.5.8.3 of this RFP. Provided further, in case the Bidding Company or Member of a Consortium, (as the case may be) holds at least twenty six percent (26%) equity in such Technically/ Financially Evaluated Entities, whose credentials have been considered for the purpose of meeting the Qualification Requirements as per the RFP, no such Undertaking shall be required from the Technically / Financially Evaluated Entities. 11. Board resolutions, as per prescribed formats enclosed as Annexure – 11, duly certified by the Company Secretary or any Whole-time Director / Manager (supported by a specific Board Resolution), as applicable to the Bidder and mentioned hereunder, (a) Board resolution from the Bidding Company (and any investing Affiliate / Parent Company / Ultimate Parent Company) committing one hundred percent (100%) in aggregate of the equity requirement for the Project - Format-1 of Annexure 11; (b) Board resolutions from each of the Consortium Member of the Bidding Consortium (and any investing Affiliate / Parent Company / Ultimate Parent Company) together committing to one hundred percent (100%) in aggregate of equity requirement for the Project, in case Bidder is a Bidding Consortium - Format-1 of Annexure 11; (c) In either of the cases as in (a) or (b) above as applicable, Board resolutions as per Format 2 of Annexure 11 for total equity investment commitment from the Technically / Financially Evaluated Entity(ies) whose technical / financial credentials had been considered for the purpose of meeting Qualification Requirements as per the RFP OR Board resolutions as per Format 2 of Annexure 11 from the Parent Company or the Ultimate Parent Company for total equity investment commitment. Provided that such Board resolutions, as specified in (a) or (b) or (c) above, in case of a foreign entity, shall be supported by an unqualified opinion issued by an independent legal counsel practicing in the relevant country, stating that the Board resolutions are in compliance with the applicable laws of the respective jurisdictions of the issuing company and the authorizations granted therein are true and valid. For clarity sake, illustrations identifying which Board Resolution shall be applicable in typical cases are provided in Annexure 11A. 12. Format for Illustration of Affiliates at the most seven (7) days prior to Bid Deadline, duly certified by Company Secretary and supported by documentary evidence (Annexure 12). REC Power Development and Consultancy Limited 37RFP for Selection of Bidder as Transmission Service Provider Certified copy of the Register of Members / Demat Account Statement, Share Certificate, Annual Return filed with ROC etc. submitted as documentary evidence along with Annexure 12. 13. Disclosure as per Annexure 13 regarding participation of any related companies in this bidding process. 14. Bid Bond, as per the prescribed format at Annexure 14 or Annexure 14A or Annexure 14B 15. Checklist for Technical Bid submission requirements as per Annexure 16. 16. Last three (3) financial years’ unconsolidated / consolidated audited annual accounts / statements, as the case may be, of the Financially Evaluated Entity / Technical Evaluated Entity 17. Unconsolidated audited annual accounts of both the TEE and the Bidding Company/Lead member, as applicable, for the financial years in which financial closure was achieved and the financial year in which the said project was completed / commissioned. 18. Copy of the Memorandum and Articles of Association and certificate of incorporation or other organizational document (as applicable), including their amendments, certified by the Company Secretary of Bidding Company or each Member in case of a Consortium including Lead Member. 19. For each project listed in Annexure 7(D), certified true copy of the certificates of final acceptance and / or certificates of good operating performance duly issued by owners or clients for the project, duly signed by duly signed by authorized signatory. In addition to the online submission of above formats through the electronic platform, the Bidder with lowest Final Offer will be required to submit original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B before issuance of LoI. In case, there is a discrepancy between the online submission and physical documents, the bid would be out rightly rejected and the bidder shall be construed to have engaged in the fraudulent practice as defined in Clause 2.19.3 with consequences as mentioned in Clause 2.19.2. 2.5.3 Financial Bid (as per prescribed format at Annexure-21) Financial Bid shall comprise of: (i) the Initial Offer; and (ii) the Final Offer. The Initial Offer is required to be submitted along with the Technical Bid. It is hereby clarified that the Financial Bid will comprise of two rounds. In the first round the Initial Offer of the responsive bids would be opened and Quoted Transmission Charges of Initial Offer shall be ranked on the basis of ascending order for determination of the Qualified Bidders as provided in Section-III of RFP. In accordance with clause 2.5 of this RFP, the qualified Bidders shall be eligible to participate in the electronic reverse auction and submit their Final Offer. REC Power Development and Consultancy Limited 38RFP for Selection of Bidder as Transmission Service Provider The applicable ceiling for electronic reverse bidding shall be the lowest Quoted Transmission Charges discovered from the Initial Offer received from the Qualified Bidders. The Qualified Bidders shall be permitted to place their Final Offer on the electronic bidding platform, which is lower than zero point two five (0.25) % of the prevailing lowest Quoted Transmission Charges. The initial period for conducting the e-reverse bidding should be 2 hours which will be extended by 30 minutes from the last received bid time, if the bid is received during the last 30 minutes of the scheduled or extended bid time. Subsequently, it will be extended again by 30 minutes from the latest received bid time. The Bidders shall inter-alia take into account the following while preparing and submitting the Initial Offer and Final Offer of Financial Bid:- a. The Bidders shall quote single annual Quoted Transmission Charges for a period of 35 years commencing from the Scheduled COD of the Project. b. The Quoted Transmission Charges as per the format at Annexure-21 shall be inclusive of all charges and no exclusions shall be allowed. The Bidders shall take into account all costs including capital and operating, statutory taxes, duties, levies. Availability of the inputs necessary for operation and maintenance of the Project should be ensured by the TSP at the Project site and all costs involved in procuring the inputs (including statutory taxes, duties, levies thereof) at the Project site must be included in the Quoted Transmission Charges. c. Annexure 21 duly digitally signed by authorized signatory. 2.5.4 Wherever information has been sought in specified formats, the Bidders shall fill in the details as per the prescribed formats and shall refrain from referring to any other document for providing any information required in the prescribed format. 2.5.5 Transmission Charges 2.5.5.1. The Transmission Charges shall be specified in the Transmission Service Agreement and shall be payable to the TSP in Indian Rupees only. The Bidders shall quote single Transmission Charges as per the format at Annexure – 21. 2.5.5.2. The Transmission Charges of the Selected Bidder shall be inserted in Schedule 5 of the Transmission Service Agreement. 2.5.6 Bidders may note that: a) All the information and documents in Bid shall be submitted in English language only. b) Bidders shall mention the name, designation, telephone number, fax number, email address of the authorized signatory and complete address of the Bidder in the covering letter. c) All pages of the Bid submitted shall be initialed and stamped by the authorized signatory on behalf of the Bidder. REC Power Development and Consultancy Limited 39RFP for Selection of Bidder as Transmission Service Provider d) A Bidder shall submit only one Bid in the same bidding process, either individually as Bidding Company or as a Member of a Bidding Consortium. e) The technical and financial capability of a particular company / particular project (Parent and/ or Affiliate) shall not be used directly or indirectly by more than one Bidder/ Member of a Bidding Consortium including Lead Member / Bidding Company. f) This Request for Proposal (RFP) document is not transferable. The RFP document and the information contained therein is for the use only by the Bidder to whom it is issued. It may not be copied or distributed by the recipient to third parties (other than in confidence to the recipient’s professional advisors). In the event that the recipient does not continue with its involvement in the Project, this RFP document must be kept confidential. g) Though adequate care has been taken while preparing this RFP document, the Bidder shall satisfy himself that the document is complete in all respects. Intimation of any discrepancy shall be given to the BPC immediately. If no intimation is received from any Bidder within ten (10) days from the date of issue of RFP document, it shall be considered that the RFP document is complete in all respects and has been received by the Bidder. h) Bids submitted by the Bidder and opened on scheduled date and time as stipulated in this RFP shall become the property of the BPC and BPC shall have no obligation to return the same to the Bidder. i) If any Bidder conceals any material information or makes a wrong statement or misrepresents facts or makes a misleading statement in its Bid, in any manner whatsoever, the BPC reserves the right to reject such Bid or cancel the Letter of Intent, if issued. If such event is discovered after the Effective Date, consequences specified in Transmission Service Agreement shall apply. j) If for any reason the Bid of the Bidder with the lowest Quoted Transmission Charges is not selected or Letter of Intent issued to such Selected Bidder is cancelled or such Bidder withdraws its Bids, the BPC may:- i. Invite all the remaining Bidders to revalidate or extend their respective Bid Security, as necessary, and match the Bid of the Bidder with the lowest Quoted Transmission Charges (the “second round of bidding”) with following cases: • If in the second round of bidding, only one Bidder matches the Bid of the Bidder with lowest Quoted Transmission Charges, it shall be the Selected Bidder. • If two or more Bidders match the Bid of the Bidder with the lowest Quoted Transmission Charges in the second round of bidding, then the Bidder whose Quoted Transmission Charges was lower as compared to other Bidder(s) in the first round of bidding shall be the Selected Bidder. For example, if the third and fifth lowest Bidders in the first round of bidding offer to match the Bid of the Bidder with lowest Quoted Transmission Charges in the second round of bidding, the said third lowest Bidder shall be the Successful Bidder. REC Power Development and Consultancy Limited 40RFP for Selection of Bidder as Transmission Service Provider • In the event that no Bidder offers to match the Bid of the Bidder with the lowest Quoted Transmission Charges in the second round of bidding, the BPC may, in its discretion, invite fresh Bids (the “third round of bidding”) from all Bidders except the Bidder which quoted the lowest Quoted Transmission Charges in the first round of bidding. In case the Bidders are invited for the third round of bidding to revalidate or extend their Bid Security, as necessary, and offer fresh Bids, they shall be eligible for submission of fresh Bids provided, however, that in such third round of bidding only such Bids shall be eligible for consideration which are lower than the Quoted Transmission Charges of the second lowest Bidder in the first round of bidding; or; ii. Annul the bid process; or iii. Take any such measure as may be deemed fit in the sole discretion of the BPC1 k) The BPC may, at its sole discretion, ask for additional information / document and/or seek clarifications from a Bidder after the Bid Deadline, inter alia, for the purposes of removal of inconsistencies or infirmities in its Bid. However, no change in the substance of the Quoted Transmission Charges shall be sought or permitted by the BPC. l) Non submission and/or submission of incomplete data/ information required under the provisions of RFP shall not be construed as waiver on the part of BPC of the obligation of the Bidder to furnish the said data / information unless the waiver is in writing. m) Bidders shall familiarize itself with the procedures and time frames required to obtain all Consents, Clearances and Permits. n) All Bidders are required to ensure compliance with the standards and codes mentioned in Clause 1.6.1.2. o) BPC reserves the right to reject all Bids and/or annul the process of tariff based competitive bidding for selection of Bidder as TSP to execute the Project without assigning any reason. BPC shall not bear any liability, whatsoever, in this regard. p) Foreign companies submitting the Bid are required to follow the applicable law in their country for execution of POA, Consortium Agreement and affixation of Common Seal (wherever required) and in such cases, their Bid should be supported by an unqualified opinion issued by an independent legal counsel practicing in the relevant country, stating that execution of such POA, Consortium Agreement and the authorizations granted therein are true and valid. Foreign companies executing POA outside India shall necessarily pay the adequate stamp charges in India as per the provisions of Stamp Act. 2.5.7 Bidders to inform themselves fully 2.5.7.1. The Bidders shall make independent enquiry and satisfy themselves with respect to all the required information, inputs, conditions and circumstances and factors that may have any effect on his Bid. Once the Bidders have submitted their Bids, the Bidders shall be 1 BPC shall record reasons for the same. REC Power Development and Consultancy Limited 41RFP for Selection of Bidder as Transmission Service Provider deemed to have inspected and examined the site conditions (including but not limited to its surroundings, its geological condition and the adequacy of transport facilities to the site), the laws and regulations in force in India, the transportation facilities available in India, the grid conditions, the adequacy and conditions of roads, bridges, railway sidings, ports, etc. for unloading and/or transporting heavy pieces of material and has based its design, equipment size and fixed its price taking into account all such relevant conditions and also the risks, contingencies and other circumstances which may influence or affect the transmission of power. Accordingly, each Bidder acknowledges that, on being selected as Successful Bidder and on acquisition of one hundred percent (100%) of the equity shares of the ……………… (Insert the name of SPV), the TSP shall not be relieved from any of its obligations under the RFP Project Documents nor shall the TSP be entitled to any extension in Scheduled COD mentioned in this RFP or financial compensation for any reason whatsoever. 2.5.7.2. In their own interest, the Bidders are requested to familiarize themselves with all relevant laws of India, including without limitation, the Electricity Act 2003, the Income Tax Act 1961, the Companies Act, 1956 / Companies Act, 2013 (as the case may be), Environment Protection Act 1986 and Forest (Conservation) Act, 1980, the Customs Act, the Foreign Exchange Management Act, Land Acquisition Act, 1894, the Indian Telegraph Act 1885, Labor & Employment Laws of India, [Insurance Act] the regulations/standards framed by the Commissions and CEA, all other related acts, laws, rules and regulations prevalent in India, as amended from time to time. In addition to the above, the Bidders are required to familiarize themselves with all relevant technical codes and standards, including but not limited to the Grid Code / State Grid Code, Central Electricity Authority (Installation and Operations of Meters) Regulations, 2006, Central Electricity Authority (Technical Standards for Connectivity to the Grid) Regulations, 2007, Central Electricity Regulatory Commission Grant of Connectivity, Long-term Access and Medium - Term Open Access in Inter-State Transmission and related matters) Regulations, 2009, Central Electricity Authority (Technical Standards for construction of Electrical Plants and Electric Lines) Regulation, 2010, Central Electricity Authority (Technical Standards for Communication System in Power System Operation) Regulations, 2020, Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020 and other relevant Rules/ Regulations/ Guidelines issued by the Central Government, the CERC and the CEA and amendments thereof. The BPC shall not entertain any request for clarifications from the Bidders regarding the above laws / acts / rules / regulations / standards. Non-awareness of the same shall not be a reason for the Bidder to request for extension in Bid Deadline. The Bidders undertake and agree that, before submission of their Bid, all such factors as generally brought out above, have been fully investigated and considered while submitting their Bids. 2.5.7.3. The Survey Report has been prepared in good faith, and on best endeavor basis. Neither BPC & Nodal Agency nor their employees or advisors/consultants make any representation or warranty, express or implied, or accept any responsibility or liability, whatsoever, in respect of any statements or omissions made in the Survey Report, or the accuracy, completeness or reliability of information contained therein, and shall incur no liability under any law, statute, rules or regulations as to the accuracy, reliability or completeness of such Survey Report, even if any loss or damage is caused to the Bidders by any act or omission on their part. REC Power Development and Consultancy Limited 42RFP for Selection of Bidder as Transmission Service Provider 2.5.7.4. Bidders shall make best efforts and carry out its own due diligence upon survey report provided by BPC and shall consider all possible techno-commercial factors before submission of Bid. Bidders may also visit the route of the Transmission Lines associated with the Project and the surrounding areas and obtain / verify all information which they deem fit and necessary for the preparation of their Bid. Bidders may also carry out required surveys and field investigation for submission of their Bid. Bidders may also opt for any other route and is not bound to follow the route suggested in survey report provided by BPC. 2.5.7.5. Failure to investigate, examine and to inspect site or subsurface conditions fully shall not be grounds for a Bidder to alter its Bid after the Bid Deadline nor shall it relieve a Bidder from any responsibility for appropriately eliminating the difficulty or costs of successfully completing the Project. 2.5.7.6. The Selected Bidder shall obtain all necessary Consents, Clearances and Permits as required. The Bidders shall familiarize itself with the procedures and time frame required to obtain such Consents, Clearances and Permits. 2.5.7.7. The technical requirements of integrated grid operation are specified in the Indian Electricity Grid Code (IEGC). The Bidders should particularly acquaint themselves with the requirements of connection conditions, operating code for regional grids, scheduling and dispatch instructions/codes, etc. The Bidders are also advised to fully familiarize themselves with the real time grid conditions in the country. Information regarding grid parameters such as voltage and frequency is available on the websites of Regional / State Load Despatch Centers. 2.5.8 Minimum Equity holding/Equity Lock-in 2.5.8.1. (a) The aggregate equity share holding of the Selected Bidder, in the issued and paid up equity share capital of ……………… (Insert the name of SPV) shall not be less than Fifty one percent (51%) up to a period of (1) one year after COD of the Project; (b) In case the Selected Bidder is a Bidding Consortium, then any Member (other than the Lead Member) of such Bidding Consortium shall be allowed to divest its equity as long as the other remaining Members (which shall always include the Lead Member) hold the minimum equity specified in (a) above. (c) If equity is held by the Affiliates, Parent Company or Ultimate Parent Company, then subject to the second proviso of this Clause 2.5.8.1 (c), such Affiliate, Parent Company or Ultimate Parent Company shall be permitted to transfer its shareholding in ……………… (Insert the name of SPV) to another Affiliate or to the Parent Company / Ultimate Parent Company. If any such shareholding entity, qualifying as an Affiliate / Parent Company / Ultimate Parent Company, is likely to cease to meet the criteria to qualify as an Affiliate / Parent Company / Ultimate Parent Company, the shares held by such entity shall be transferred to another Affiliate / Parent Company / Ultimate Parent Company. Provided that in case the Lead Member or Bidding Company is holding equity through Affiliate/s, Ultimate Parent Company or Parent Company, such restriction shall apply to such entities. REC Power Development and Consultancy Limited 43RFP for Selection of Bidder as Transmission Service Provider Provided further, that the aggregate equity share holding of the Bidding Consortium or a Bidding Company in the issued and paid up equity share capital of ……………… (Insert the name of SPV) shall not be less than fifty one percent (51%) up to a period of one (1) year after COD of the Project and the lead Member of the Consortium shall have the equity share holding not less than twenty six percent (26%). In case the Selected Bidder is a Bidding Consortium, then any Member (other than the Lead Member) of such Bidding Consortium shall be allowed to divest its equity as long as the other remaining Members (which shall always include the Lead Member) hold the minimum equity specified in (a) above. (d) All transfer(s) of shareholding of ……………… (Insert the name of SPV) by any of the entities referred to above, shall be after prior written intimation to the Nodal Agency. 2.5.8.2. The Selected Bidder may invest in the equity share capital of ……………… (Insert the name of SPV) through its Affiliate(s) or Ultimate Parent Company or Parent Company. Details of such investment will have to be specified in the Technical Bid as per Format 2 of Annexure 8 of the RFP. If the Selected Bidder so invests through any Affiliate(s) or Ultimate Parent Company or Parent Company, the Selected Bidder shall be liable to ensure that minimum equity holding/lock-in limits specified in Clause 2.5.8.1 and as computed as per the provisions of Clause 2.5.8.3 are still maintained. 2.5.8.3. For computation of effective Equity holding, the Equity holding of the Selected Bidder or its Ultimate Parent Company in such Affiliate(s) or Parent Company and the equity holding of such Affiliate (s) or Ultimate Parent Company in ……………… (Insert the name of SPV) shall be computed in accordance with the example given below: If the Parent Company or the Ultimate Parent Company of the Selected Bidder A directly holds thirty percent (30%) of the equity in ……………… (Insert the name of SPV) then holding of Selected Bidder A in ……………… (Insert the name of SPV) shall be thirty percent (30%); If Selected Bidder A holds thirty percent (30%) equity of the Affiliate and the Affiliate holds fifty percent (50%) equity in ……………… (Insert the name of SPV), then for the purposes of ascertaining the minimum equity/equity lock-in requirements specified above, the effective holding of Bidder A in ……………… (Insert the name of SPV) shall be fifteen percent (15%), (i.e., 30%* 50%); 2.5.8.4. The provisions as contained in this Clause 2.5.8 and Article 19.1 of the Transmission Service Agreement shall override the terms of the Consortium Agreement submitted by the Bidder as part of the RFP. 2.6 Project Schedule 2.6.1. All Elements of the Project are required to be commissioned progressively as per the schedule given in the following table: REC Power Development and Consultancy Limited 44RFP for Selection of Bidder as Transmission Service Provider Sl. Name of the Transmission Scheduled % of Quoted Element(s) which No. Element COD as per Transmission are pre-required Gazette Charges for declaring the Notification recoverable on commercial Scheduled COD operation (COD) of the Element of of the respective the Project Element Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) Element at Sl. GIS substation with 1x330 MVAr 1. No. 2, 3, 4, 5, (765 kV) bus reactor with space 6, 7 & 8 provision for establishment of 220 kV switchyard ± 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi Element at Sl. (Vizag) GIS with control 2. No. 1, 3, 4, 5, switching arrangement for 6, 7 & 8 proposed 1x330 MVAr bus reactor Pendurthi (Vizag) – Srikakulam Element at Sl. 765 kV D/c line with 330 MVAr 3. No. 1, 2, 4, 5, SLR (convertible) at Srikakulam 6, 7 & 8 end on both circuits LILO of Kalpakka – Maradam Element at Sl. 4. 400 kV (quad) D/c line at No. 1, 2, 3, 5, 30 Months 100 Pendurthi 6, 7 & 8 Establishment of 3x1500 MVA, 765/400 kV Khammam-II Element at Sl. substation with 1x330 MVAr (765 5. No. 1, 2, 3, 4, kV) bus reactor with space 6, 7 & 8 provision for establishment of 220 kV switchyard Element at Sl. Khammam-II – Warangal New 6. No. 1, 2, 3, 4, 765 kV D/c line 5 ,7 & 8 Khammam-II – Pendurthi (Vizag) Element at Sl. 765 kV D/c line with 330 MVAr 7. No. 1, 2, 3, 4, SLR (convertible) at both ends on 5, 6 & 8 both circuits Element at Sl. Khammam-II – Khammam 8. No. 1, 2, 3, 4, (existing) 400 kV (quad) D/c line 5, 6 & 7 REC Power Development and Consultancy Limited 45RFP for Selection of Bidder as Transmission Service Provider The payment of Transmission Charges for any Element irrespective of its successful commissioning on or before its Scheduled COD shall only be considered after successful commissioning of the Element(s) which are pre-required for declaring the commercial operation of such Element as mentioned in the above table. Scheduled COD for overall Project: 30 months. Note: List of Element(s) along with the critical Element(s) to be provided by CEA. 2.7 Due dates 2.7.1. The Bidders should submit the Bids online through the electronic bidding platform before the Bid Deadline i.e. on or before 1500 hours (IST) on 07.04.2026. In addition to the online submission, the Bidder with lowest Final Offer will be required to submit original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B before issuance of LoI. 2.7.2. Important timelines are mentioned below: Date Event 03.02.2026 Issuance of RFP Submission of written clarifications/amendments, if any, on the RFP / RFP Project Documents by Bidders so as to reach BPC by 23.02.2026 1700 hours. Such written clarifications/amendments shall be in the format provided in Annexure-20. 26.02.2026 Pre-Bid meeting(s) 13.03.2026 Issue of written clarifications and revised RFP documents 23.03.2026 Issue of final RFP Project Documents Submission of Bid (Online submission of Bid through electronic 07.04.2026 bidding portal) 07.04.2026 Opening of Technical Bid Short listing and announcement of Qualified Bidders on bidding 15.04.2026 portal 16.04.2026 Opening of Financial Bid - Initial Offer Electronic reverse auction (Financial Bid – Final Offer) for the 17.04.2026 Qualified Bidders. Submission of original hard copies of Annexure 3, Annexure 4, 22.04.2026 Annexure 6, as applicable and Annexure 14/14A/14B by the bidder with lowest Final Offer 27.04.2026 Selection of Successful Bidder and issue of LOI Signing of RFP Project Documents and transfer of ……………… 07.05.2026 (Insert the name of SPV) 2.7.3. To enable BPC to meet the schedule, all Bidders are expected to respond expeditiously during the bidding process. If any milestone/activity falls on a day which is not a working day or which is a public holiday then the milestone/activity shall be achieved/ completed on the next working day. 2.8 Validity of the Bid REC Power Development and Consultancy Limited 46RFP for Selection of Bidder as Transmission Service Provider 2.8.1. The Bid shall remain valid for a period of one hundred and eighty (180) days from the Bid Deadline. The BPC reserves the right to reject any Bid which does not meet aforementioned validity requirement. 2.8.2. The BPC may solicit the Bidders’ consent for an extension of the period of validity of the Bid. The request and the response, thereafter, shall be in writing. In the event any Bidder refuses to extend its Bid validity as requested by the BPC, the BPC shall not be entitled to invoke the Bid Bond. A Bidder accepting the BPC’s request for validity extension shall not be permitted to modify its Bid and such Bidder shall, accordingly, extend the validity of the Bid Bond as requested by the BPC within seven (7) days of such request, failing which the Bid shall not be considered as valid. 2.9 Method of Submission 2.9.1. Both the Technical and Financial Bids duly filled in, all formats and supporting shall be scanned and uploaded online through electronic bidding platform in the manner specified in Annexure A 2.9.2. It may be noted that Technical Bid shall not contain any information/document relating to Financial Bid. If Technical Bid contains any such information/documents, the BPC shall not be responsible for premature opening of the Financial Bid. All pages of the Bid, except for the Bid Bond (Annexure 14/14A/14B) and any other document executed on non-judicial stamp paper, forming part of the Bid and corrections in the Bid, if any, must be signed by the authorized signatory on behalf of the Bidder. It is clarified that the same authorized signatory shall sign all pages of the Bid. However, any published document submitted in this regard shall be signed by the authorized signatory at least on the first and last page of such document. 2.9.3. No change or supplemental information to a Bid already submitted will be accepted after the Bid Deadline, unless the same is requested for by the BPC as per Clause 2.5.6 (k). Provided that a Bidder shall always have the right to withdraw / modify its Bid before the Bid Deadline. No Technical Bid or Initial Offer shall be modified, substituted or withdrawn by the Bidder on or after the Bid Deadline. 2.10 Preparation cost 2.10.1. The Bidders shall be responsible for all the costs associated with the preparation of the Bid and participation in discussions and attending pre-bid meetings, and finalization and execution of the RFP Project Documents (other than the TSA), etc. BPC shall not be responsible in any way for such costs, regardless of the conduct or outcome of the process of tariff based competitive bidding for selection of Bidder as TSP as per Bidding Guidelines. 2.10.2. The cost of this RFP is Rupees Five Lakh Only (Rs. 5,00,000) or U.S. Dollar Seven Thousand Only (US$ 7,000) plus GST as per applicable rate, which shall be non-refundable. This amount shall be paid via electronic transfer to the following Bank Account: REC Power Development and Consultancy Limited 47RFP for Selection of Bidder as Transmission Service Provider Bank Name, Address ICICI Bank & Branch 9A, Phelps Building, Inner Circle, Connaught Place, New Delhi- 110001 Bank Account Name REC Power Development & Consultancy Limited Bank Account No 000705041275 Bank IFSC Code No ICIC0000007 Immediately after issuance of RFP document, the Bidder shall submit the Pre-Award Integrity Pact in the format as prescribed in Annexure B, which shall be applicable for and during the bidding process, duly signed on each page by any whole-time Director / Authorized Signatory, duly witnessed by two persons, and shall be submitted by the Bidder in two (2) originals in a separate envelope, duly superscripted with Pre-Award Integrity Pact. The Bidder shall submit the Pre-Award Integrity Pact on non-judicial stamp paper of Rs. 100/- each duly purchased from the National Capital Territory of Delhi. In case the Bidder is in a consortium, the Pre-Award Integrity Pact shall be signed and submitted by each member of the Consortium separately. 2.11 Bid Bond 2.11.1. Each Bidder shall submit the Bid accompanied by Bid Bond issued by any of the Banks listed in Annexure-17. The Bid Bond shall be valid for a period of thirty (30) days beyond the validity of the Bid. 2.11.2. Subject to the provisions of Clause 2.15.5, the Bid Bond may be invoked by the BPC or its authorized representative, without any notice, demure, or any other legal process upon occurrence of any of the following:  Bidder withdraws during the period of Bid Validity as specified in this RFP or as extended by mutual consent of the respective Bidder(s) and the BPC  Failure to execute the Share Purchase Agreement as per the provisions of Clause 2.15.2; or  Failure to furnish the Contract Performance Guarantee as per Clause f; or  Failure to acquire one hundred percent (100%) equity shares of ……………… (Insert the name of SPV), along with all its related assets and liabilities, in accordance with the provisions of Clause 2.15.2; or  Failure to comply with the provisions of Clause 2.15.5 and Clause 2.15.6, leading to annulment of the award of the Project.  Bidders submitting any wrong information or making any misrepresentation in their Bid as mentioned in Clause 2.5.6. Intimation of the reasons of the invocation of the Bid Bond shall be given to the Selected Bidder by the BPC within three (3) working days after such invocation. 2.11.3. The Bid Bond of the Selected Bidder shall be returned on submission of the Contract Performance Guarantee as per Clause 2.12 and the relevant provisions of the Transmission Service Agreement. REC Power Development and Consultancy Limited 48RFP for Selection of Bidder as Transmission Service Provider 2.11.4. The Bid Bond of all the Bidders, whose Bids are declared non-responsive, shall be returned within a period of thirty (30) days after the date on which the Financial Bids are opened. 2.11.5. The Bid Bond of all unsuccessful Bidders shall be returned and released by the BPC on the same day on which the ……………… (Insert the name of SPV) is transferred to the Selected Bidder. The Bid Bond of the Successful Bidder shall be returned on submission of Contract Performance Guarantee as per Clause 2.12 of this RFP and the provisions of the Transmission Service Agreement. 2.12 Contract Performance Guarantee Within ten (10) days from the date of issue of the Letter of Intent, the Selected Bidder, on behalf of the TSP, will provide to the Nodal Agency the Contract Performance Guarantee for an amount of Rs. 196.75 Crore (Rupees One Hundred Ninety-Six Crore and Seventy- Five Lakh Only). The Contract Performance Guarantee shall be initially valid for a period up to three (3) months after the Scheduled COD of the Project and shall be extended from time to time to be valid for a period up to three (3) months after the COD of the Project and thereafter shall be dealt with in accordance with the provisions of the Transmission Service Agreement. The Contract Performance Guarantee shall be issued by any of the banks listed in Annexure-17 as per format given at Annexure- 15 or any of the insurance companies authorized by Insurance Regulatory and Development Authority of India as per format given at Annexure – 15A or PFC/ REC/ IREDA as per Payment on Order Instrument format given at Annexure -15B. 2.12.1. In case the Selected Bidder is unable to obtain the Contract Performance Guarantee for the total amount from any one bank specified in Annexure-17, the Selected Bidder may obtain the same from not more than three (3) banks specified in Annexure-17. 2.13 Opening of Bids 2.13.1. Technical Bid will be opened by the Bid Opening Committee as per the following time schedule and in the office of Central Electricity Authority, in the online presence of Bidders’ representatives who wish to attend: Opening of Envelope (Technical Bid): 1530 hours (IST) on 07.04.2026 or such other dates as may be intimated by BPC to the Bidders. In the event of any of above dates falling on a day which is not a working day or which is a public holiday, then the bids shall be opened on the next working day at the same venue and time. Opening of Initial Offer: Initial Offer shall be opened by the Bid Opening Committee in presence of the Bid Evaluation Committee at 1530 hours (IST) on 16.04.2026 in the office of CEA. 2.13.2. The following information from each Bid will be read out to all the Bidders at the time of opening of Technical Bid: REC Power Development and Consultancy Limited 49RFP for Selection of Bidder as Transmission Service Provider  • Name of the Bidding Company / Consortium Members in case of Bidding Consortium. Information to be provided after opening of Initial Offer: Only the lowest Initial Offer (s) shall be communicated to all the Qualified Bidders to participate in the e-reverse bidding process. During the e-reverse bidding process only the lowest prevailing bid should be visible to all the bidders on the electronic platform. 2.14 Enquiries Written clarifications on the RFP and other RFP Project Documents as per Clause 2.3 and 2.4 may be sought from: Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Email: vijay.kulkarni@recpdcl.in & tbcb@recpdcl.in 2.15 Other Aspects 2.15.1. The draft of the Transmission Service Agreement has been attached to this RFP. In addition to above, the following documents have also been attached to this RFP: a) Share Purchase Agreement When the drafts of the above RFP Project Documents are provided by the BPC, these RFP Project Documents shall form part of this RFP as per Formats – 1 & 2 of Annexure 20. Upon finalization of the RFP Project Documents after incorporating the amendments envisaged in Clause 2.4 of this RFP, all the finalized RFP Project Documents shall be provided by BPC to the Bidders at least fifteen (15) days prior to the Bid Deadline. The Transmission Service Agreement and Share Purchase Agreement shall be signed in required number of originals so as to ensure that one (1) original is retained by each party to the Agreement(s) on the date of transfer of SPV. 2.15.2. Within ten (10) days of the issue of the Letter of Intent, the Selected Bidder shall: a) provide the Contract Performance Guarantee in favour of the Nodal Agency as per the provisions of Clause 2.12; b) execute the Share Purchase Agreement and the Transmission Service Agreement; c) acquire, for the Acquisition Price, one hundred percent (100%) equity shareholding of ……………… (Insert the name of SPV) from REC Power Development and Consultancy Limited, who shall sell to the Selected Bidder, the equity shareholding REC Power Development and Consultancy Limited 50RFP for Selection of Bidder as Transmission Service Provider of ……………… (Insert the name of SPV), along with all its related assets and liabilities; Stamp duties payable on purchase of one hundred percent (100%) of the equity shareholding of ……………… (Insert the name of SPV), along with all its related assets and liabilities, shall also be borne by the Selected Bidder. Provided further that, if for any reason attributable to the BPC, the above activities are not completed by the Selected Bidder within the above period of ten (10) days as mentioned in this Clause, such period of ten (10) days shall be extended, on a day for day basis till the end of the Bid validity period. 2.15.3. After the date of acquisition of the equity shareholding of ……………… (Insert the name of SPV), along with all its related assets and liabilities, by the Selected Bidder, i. the authority of the BPC in respect of this Bid Process shall forthwith cease and any actions to be taken thereafter will be undertaken by the Nodal Agency, ii. all rights and obligations of ……………… (Insert the name of SPV), shall be of the TSP, iii. any decisions taken by the BPC prior to the Effective Date shall continue to be binding on the Nodal Agency and iv. contractual obligations undertaken by the BPC shall continue to be fulfilled by the TSP. v. Further, the TSP shall execute the Agreement(s) required, if any, under Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time. 2.15.4. Within five (5) working days of the issue of the acquisition of the SPV by the Successful Bidder, the TSP shall apply to the Commission for grant of Transmission License and make an application to the Commission for the adoption of Transmission Charges, as required under Section – 63 of The Electricity Act 2003. 2.15.5. If the Selected Bidder / TSP fails or refuses to comply with any of its obligations under Clauses 2.15.2, 2.15.3 and 2.15.4, and provided that the other parties are willing to execute the Share Purchase Agreement and REC Power Development and Consultancy Limited is willing to sell the entire equity shareholding of ……………… (Insert the name of SPV), along with all its related assets and liabilities, to the Selected Bidder, such failure or refusal on the part of the Selected Bidder shall constitute sufficient grounds for cancellation of the Letter of Intent. In such cases, the BPC / its authorized representative(s) shall be entitled to invoke the Bid Bond of the Selected Bidder. 2.15.6. If the TSP fails to obtain the Transmission License from the Commission, it will constitute sufficient grounds for annulment of award of the Project. 2.15.7. The annulment of award, as provided in Clauses 2.15.5 and 2.15.6 of this RFP, will be done by the Government on the recommendations of National Committee on Transmission. However, before recommending so, National Committee on Transmission REC Power Development and Consultancy Limited 51RFP for Selection of Bidder as Transmission Service Provider will give an opportunity to the Selected Bidder / TSP to present their view point. 2.15.8. The annulment of the award, under Clause 2.15.5 or 2.15.6 of this RFP, shall be sufficient grounds for blacklisting the bidder, whose award has been annulled, for a period of five years or more, as decided by the National Committee on Transmission, provided that the blacklisting shall be done only after giving the bidder an opportunity for showing cause. 2.16 Confidentiality 2.16.1. The parties undertake to hold in confidence this RFP and RFP Project Documents and not to disclose the terms and conditions of the transaction contemplated hereby to third parties, except: a) to their professional advisors; b) to their officers, contractors, employees, agents or representatives, financiers, who need to have access to such information for the proper performance of their activities; c) disclosures required under Law, without the prior written consent of the other parties of the concerned agreements. Provided that the TSP agrees and acknowledges that the Nodal Agency may at any time, disclose the terms and conditions of the RFP and RFP Project Documents to any person, to the extent stipulated under the Law or the Bidding Guidelines. 2.17 Right of the BPC to reject any Bid BPC reserves the right to reject all or any of the Bids/ or cancel the RFP without assigning any reasons whatsoever and without any liability. 2.18 Non submission and/or submission of incomplete data/ information required under the provisions of RFP shall not be construed as waiver on the part of BPC of the obligation of the Bidder to furnish the said data / information unless the waiver is in writing. 2.19 Fraudulent and Corrupt Practices 2.19.1. The Bidders and their respective officers, employees, agents and advisers shall observe the highest standard of ethics during the Bid process and subsequent to the issue of the LoI Notwithstanding anything to the contrary contained herein, or in the LoI, the BPC shall reject a Bid, withdraw the LoI, as the case may be, without being liable in any manner whatsoever to the Bidder, if it determines that the Bidder has, directly or indirectly or through an agent, engaged in corrupt practice, fraudulent practice, coercive practice, undesirable practice or restrictive practice in the Bid process. In such an event, the BPC shall forfeit the Bid Bond, without prejudice to any other right or remedy that may be available to the BPC hereunder or otherwise. 2.19.2. Without prejudice to the rights of the BPC under Clause 2.19.1 hereinabove and the rights and remedies which the BPC may have under the LoI, if a Bidder is found by the BPC to have directly or indirectly or through an agent, engaged or indulged in any corrupt practice, fraudulent practice, coercive practice, undesirable practice or restrictive practice during REC Power Development and Consultancy Limited 52RFP for Selection of Bidder as Transmission Service Provider the Bid process, or after the issue of the LoI, such Bidder & its Affiliates shall not be eligible to participate in any tender or RFP issued by any BPC for an indefinite period from the date such Bidder is found by the BPC to have directly or indirectly or through an agent, engaged or indulged in any corrupt practice, fraudulent practice, coercive practice, undesirable practice or restrictive practices, as the case may be. 2.19.3. For the purposes of this Clause 2.19, the following terms shall have the meaning hereinafter respectively assigned to them: a) “corrupt practice” means (i) the offering, giving, receiving, or soliciting, directly or indirectly, of anything of value to influence the actions of any person connected with the Bid process (for avoidance of doubt, offering of employment to or employing or engaging in any manner whatsoever, directly or indirectly, any official of the BPC who is or has been associated or dealt in any manner, directly or indirectly with the Bid process or the LoI or has dealt with matters concerning the Transmission Service Agreement or arising there from, before or after the execution thereof, at any time prior to the expiry of one year from the date such official resigns or retires from or otherwise ceases to be in the service of the BPC, shall be deemed to constitute influencing the actions of a person connected with the Bid Process); or (ii) engaging in any manner whatsoever, whether during the Bid Process or after the issue of the LoI or after the execution of the Transmission Service Agreement, as the case may be, any person in respect of any matter relating to the Project or the LoI or the Transmission Service Agreement, who at any time has been or is a legal, financial or technical adviser of the BPC in relation to any matter concerning the Project; b) "Fraudulent practice" means a misrepresentation or omission of facts or suppression of facts or disclosure of incomplete facts, in order to influence the Bid process; c) “Coercive practice” means impairing or harming, or threatening to impair or harm, directly or indirectly, any person or property to influence any person’s participation or action in the Bid process; d) "undesirable practice" means (i) establishing contact with any person connected with or employed or engaged by the BPC with the objective of canvassing, lobbying or in any manner influencing or attempting to influence the Bid process; or (ii) having a Conflict of Interest; and e) "Restrictive practice" means forming a cartel or arriving at any understanding or arrangement among Bidders with the objective of restricting or manipulating a full and fair competition in the Bid process. REC Power Development and Consultancy Limited 53RFP for Selection of Bidder as Transmission Service Provider SECTION - 3 EVALUATION OF THE TECHNICAL AND FINANCIAL BID REC Power Development and Consultancy Limited 54RFP for Selection of Bidder as Transmission Service Provider SECTION 3 1. EVALUATION OF BID 3.1. The evaluation process of Technical Bid comprises the following five steps: Step I – Responsiveness check Step II- Compliance with submission requirements Step III– Evaluation of Technical Bids Step IV– Evaluation of Financial Bids Step V – Bidder Selection 3.2. STEP I – Responsiveness check The Technical Bid submitted by the Bidder shall be initially scrutinized to establish “Responsiveness”. Subject to clause 2.5.6 (k), any of the following conditions shall cause the Technical Bid to be “Non-responsive”: a) Technical Bid that are incomplete. b) Technical Bid not signed by authorized signatory and / or stamped in the manner indicated in this RFP. c) All pages of the Technical Bid submitted but not initialed by the authorized signatories on behalf of the Bidder. d) Technical Bid not including the covering letter as per Annexure 1. e) Technical Bid submitted by a Bidding Consortium not including the Consortium Agreement. f) Technical Bid contains material inconsistencies in the information and documents submitted by the Bidder, affecting the Qualification Requirements. g) Bidder submitting or participating in more than one Bid either as a Bidding Company or as a Member of Bidding Consortium. h) More than one Member of the Bidding Consortium or a Bidding Company using the credentials of the same Parent/Affiliate. i) Information not submitted in formats specified in the RFP. j) Applicable Board resolutions, or any other document, as provided in Clause 2.5.2, not being submitted; k) Bid not accompanied by a valid Bid Bond; l) Non submission of power of attorney, supported by a Board resolution; m) Bid validity being less than that required as per Clause 2.8 of this RFP; n) Bid not containing Format-1 (Bidders' Undertakings) of Annexure-8; REC Power Development and Consultancy Limited 55RFP for Selection of Bidder as Transmission Service Provider o) Bidder having Conflict of Interest p) The Bidder has not submitted a disclosure as per Annexure 13. q) Bidders delaying in submission of additional information or clarifications sought by the BPC. r) If the Bidder makes any misrepresentation as specified in Clause 3.7. s) Bid being conditional in nature. t) More than one Member of the Bidding Consortium or a Bidding Company using the credentials of the same Parent/Affiliate. 3.3. STEP II - Compliance with submission requirements Each Bidder’s Technical Bid shall be checked for compliance with the submission requirements set forth in this RFP before the evaluation of Technical Bid is taken up. Annexure 16 and Annexure 11A shall be used to check whether each Bidder meets the stipulated requirements. 3.4. STEP III -Evaluation of Technical Bid Evaluation of Technical Bid will be carried out considering the information and documents furnished by the Bidders as required under this RFP. This step would involve technical and financial evaluation of the details/ documents furnished by the Bidding Company / Bidding Consortium in support of meeting the Qualification Requirements 3.4.1. Interpolation of financial data. For the Qualification Requirements data provided by the Bidders in foreign currency, equivalent rupees of Net-worth will be calculated using bills selling exchange rates (card rate) USD/INR of State Bank of India prevailing on the date of closing of the accounts for the respective financial year as certified by their Banker. For the purpose of calculating the aggregate capital expenditure/construction experience of the projects completed/ commissioned where such projects are executed outside India and capital expenditure is denominated in foreign currency, bills selling exchange rates (card rate) USD/INR of State Bank of India prevailing on the date of closing of the financial year in which the projects were completed and as certified by their Banker shall be considered. For the projects executed in the current financial year bills selling (card rate) USD/INR of State Bank of India prevailing on seven (7) days prior to the last date of submission of Technical Bid and as certified by their Banker shall be considered. For currency other than USD, Bidders shall convert such currency into USD as per the exchange rates certified by their Banker prevailing on the relevant date and used for such conversion. Such Bidders shall submit necessary certification from their Banker for the exchange rate used in the conversation. REC Power Development and Consultancy Limited 56RFP for Selection of Bidder as Transmission Service Provider If the exchange rate for any of the above dates is not available, the rate for the immediately available previous day shall be taken into account. 3.4.2. Bidders meeting the Qualification Requirements, subject to evaluation as specified in Clauses 3.2 to 3.4 shall be declared as Qualified Bidders and eligible for opening of Initial Offer. 3.4.3. The BPC shall upload the list of all Qualified Bidders and Non-Qualified Bidders on the bidding portal along with the reasons for non-qualification. 3.5. STEP IV - Evaluation of Financial Bids 3.5.1. The Bids which have been found Qualified by the BPC, based on the Steps I to III as specified above in Clauses 3.2.to 3.4, shall be opened and Quoted Transmission Charges of such Initial Offer shall be ranked on the basis of the ascending Initial Offer submitted by each Qualified Bidder. Based on such ranking of the Qualified Bidders, in the first fifty per cent of the ranking (with any fraction rounded off to higher integer) or four Qualified Bidders, whichever is higher, shall qualify for participating in the electronic reverse auction. Provided however, in case only one Bidder remains after the Evaluation of Technical Bid (Steps 1 to III) as per Clause 3.2 to 3.4, the Initial Offer of such Bidder shall not be opened and the matter shall be referred to the Government. Provided that in the event the number of Qualified Bidders is between two and four, then each of the responsive Bidder shall be considered as Qualified Bidders. Provided that in the event of identical Quoted Transmission Charges discovered from the Initial Offer having been submitted by one or more Bidders, all such Bidders shall be assigned the same rank for the purposes of determination of Qualified Bidders. In such cases, all Qualified Bidders who shares the same rank till 50% of the rank (with any faction rounded off to higher integer) determined above, shall qualify to participate in the electronic reverse auction stage. In case 50% of the rank is having less than four (4) Bidders and the rank of the fourth (4th) Bidder is shared by more than one Bidder, then all such all such Bidders who share the rank of the fourth Bidder shall qualify to participate in the electronic reverse auction. 3.5.2. The Financial Bids comprising of both Initial Offer and Final Offer submitted by the Bidders shall be scrutinized to ensure conformity with the provisions of Clause 2.5.3 of this RFP. Any Bid not meeting any of the requirements as per Clause 2.5.3 of this RFP may cause the Bid to be considered "Non-responsive", at the sole decision of the BPC. Financial Bid not in conformity with the requirement of SI. No. (c) of Clause 2.5.3 of this RFP shall be rejected. 3.5.3 The Bidders shall quote the single annual Quoted Transmission Charges as specified in the format at Annexure – 21. 3.6. STEP V - Bidder Selection REC Power Development and Consultancy Limited 57RFP for Selection of Bidder as Transmission Service Provider 3.6.1. The prevailing lowest Quoted Transmission Charges discovered from Final Offers shall only be displayed during the e-reverse bidding and the Bidder quoting such Final Offer will always remain anonymous during the e-reverse bidding. The Bidder with the prevailing lowest Quoted Transmission Charges discovered from Final Offers at the close of the scheduled or extended period of e-reverse bidding as mentioned in clause 2.5 shall be declared as the Successful Bidder, subject to verification of the original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B. The Letter of Intent shall be issued to such Successful Bidder in two (2) copies. However, if no bid is received during the e-reverse bidding stage then the Bidder with lowest quoted initial transmission charges ("Initial Offer") during e-bidding stage shall be declared as the Successful Bidder, subject to verification of the original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B. The Letter of Intent shall be issued to such Successful Bidder in two (2) copies. In case, there is a discrepancy between the online submission and physical documents, the bid would be out rightly rejected and the bidder shall be construed to have engaged in the fraudulent practice as defined in Clause 2.19.3 with consequences as mentioned in Clause 2.19.2. Further, in such a case, the provisions of Clause 2.5.6 (j) shall apply. 3.6.2. The Selected Bidder shall unconditionally accept the LoI, and record on one (1) copy of the LoI, "Accepted unconditionally", under the signature of the authorized signatory of the Successful Bidder and return such copy to the BPC within seven (7) days of issue of LoI. 3.6.3. If the Successful Bidder, to whom the Letter of Intent has been issued, does not fulfill any of the conditions specified in Clauses 2.15.2, 2.15.3 and Clause 2.15.4, then subject to Clause 2.15.5, the BPC reserves the right to annul the award of the Project and cancel the Letter of Intent. Further, in such a case, the provisions of Clause 2.5.6 (j) shall apply. 3.6.4. The BPC, in its own discretion, has the right to reject all Bids if the Quoted Transmission Charges are not aligned to the prevailing prices. 3.7. Misrepresentation by the Bidder If the Bidder conceals any material information or makes a wrong statement or misrepresents facts or makes a misleading statement in the Technical Bid or Bid, as the case may be, in any manner whatsoever, in order to create circumstances for the acceptance of its Technical Bid/Bid, the BPC reserves the right to reject such Technical Bid/Bid, and/ or cancel the Letter of Intent, if issued. Further, in case Letter of Intent is cancelled, consequences as per provisions of the RFP shall follow. 3.8. Disposition of Technical Bid 3.8.1. Technical Bid found to be Non-responsive as per Clause 3.2, due to any of the following conditions, shall be liable for rejection.  Technical Bid that is incomplete.  Technical Bid not signed by authorized signatory and / or stamped in the manner indicated in this RFP.  All pages of the Technical Bid submitted but not initialed by the authorized signatories on behalf of the Bidder. REC Power Development and Consultancy Limited 58RFP for Selection of Bidder as Transmission Service Provider  Technical Bid not including the covering letter as per Annexure 1.  Technical Bid contains material inconsistencies in the information and documents submitted by the Bidder, affecting the Qualification Requirements.  Information not submitted in formats specified in the RFP.  The Bidder has not submitted a disclosure as per Annexure 13.  Bidders delaying in submission of additional information or clarifications sought by the BPC. 3.8.2. Technical Bid found to be Non-responsive as per Clause 3.2, due to any of the following conditions, shall be rejected.  Technical Bid not received by the scheduled date and time.  Technical Bid submitted by a Bidding Consortium not including the Consortium Agreement.  Bidder submitting or participating in more than one response either as a Bidding Company or as a Member of Bidding Consortium.  More than one Member of the Bidding Consortium or a Bidding Company using the credentials of the same Parent/Affiliate.  Technical Bid having Conflict of Interest.  If the Bidder makes any misrepresentation as specified in Clause 3.7. 3.9. BPC reserves the right to interpret the Bid in accordance with the provisions of this RFP document and make its own judgment regarding the interpretation of the same. In this regard, BPC shall have no liability towards any Bidder and no Bidder shall have any recourse to BPC with respect to the qualification process. BPC shall evaluate Bid using the process specified in Clause 3.1 to 3.6, at its sole discretion. BPC’s decision in this regard shall be final and binding. REC Power Development and Consultancy Limited 59RFP for Selection of Bidder as Transmission Service Provider SECTION - 4 ANNEXURES FOR BID REC Power Development and Consultancy Limited 60RFP for Selection of Bidder as Transmission Service Provider SECTION – 4 I. Formats for Bid The following formats are required to be included in the Bidder’s Technical and Financial Bid. These formats are designed to demonstrate the Bidder’s compliance with the Qualification Requirements set forth in Clause 2.1 of Section – 2. Technical Bid 1. Format for the Covering Letter 2. Format for Letter of Consent from Consortium Members 3. Format for evidence of authorized signatory’s authority (Power of Attorney) 4. Format for Power of Attorney from to be provided by each of the other Members of the Consortium in favor of the Lead Member 5. Format for Bidder’s composition and ownership structure and Format for Authorization 6. Format for Consortium Agreement 7. Formats for Qualification Requirement 8. Format of Bidders Undertaking and details of Equity Investment 9. Authorization from Parent/Affiliate of Bidding Company/Member of Bidding Consortium whose technical/financial capability has been used by the Bidding Company/Member of Bidding Consortium. 10. Undertaking from the Technically / Financially Evaluated Entity(ies) or from Ultimate Parent Company for equity investment 11. Format of Board Resolutions 12. Format for Illustration of Affiliates 13. Format for Disclosure 14. Format for Bid Bond 14A. Format of the Surety Bond for Bid Security 14B Format of Payment on Order Instrument to be issued by IREDA/REC/PFC 15. Format for Contract Performance Guarantee 15A. Format for Surety Insurance Contract 15B. Format for issuance of Payment on Order Instrument 16. Checklist for Technical Bid submission requirements 22. Format for Affidavit In addition to the online submission, the Bidder with lowest Final Offer will be required to submit original hard copies of Annexure 3, Annexure 4 (if applicable), Annexure 6 (if applicable) and Annexure 14/14A/14B before issuance of LoI. Financial Bid 21. Format for Financial Bid II. The following formats are for the information to the Bidders to enable them to submit their Bid. 11A. Illustration For Applicable Board Resolution Requirements Under Clause 2.5.2 17. List of Banks 18. GRID Map of the Project 19. Format for clarification/amendments on the RFP/RFP Project Documents 20. Formats for RFP Project Documents Bidder may use additional sheets to submit the information for its detailed Bid. REC Power Development and Consultancy Limited 61RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 1 - COVERING LETTER (The covering letter should be on the Letter Head of the Bidding Company/ Lead Member of the Consortium) Date: ………………………………… From: ………………………………… ………………………………… ………………………………… Tel. No.: …................................................ Fax No.: .................................................... E-mail address: .................................................. To, Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission Scheme under “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process. 1. Being duly authorized to present and act on behalf of M/s …………………. (insert name of Bidding Company / Bidding Consortium) (hereinafter called the “Bidder”) and having read and examined in detail the Request for Proposal (RFP) document, the undersigned hereby submit our Technical Bid with duly signed formats and Financial Bid (Initial Offer) as stipulated in RFP document for your consideration. 2. It is confirmed that our Bid is consistent with all the requirements of submission as stated in the RFP document and subsequent clarifications/amendments as per Clause 2.3 and 2.4 of RFP. 3. The information submitted in our Bid is complete, is strictly as per the requirements stipulated in the RFP document and is correct to the best of our knowledge and understanding. We would be solely responsible for any errors or omissions in our Bid. 4. We hereby agree and undertake to procure the products associated with the Transmission System as per provisions of Public Procurement (Preference to Make in India) orders issued by Ministry of Power vide orders No. 11/5/2018 - Coord. dated 28.07.2020 for transmission sector, as amended vide order No. A-1/2021-FSC- Part(5) dated 16.11.2021 and No.: P45021/2/2017-PP (BE-II)-Part-4 Vol.II dated 19.07.2024 issued by Ministry of Power for transmission sector, as may be further amended from time to time read with Department for Promotion of Industry and Internal Trade (DPIIT) orders in this regard. REC Power Development and Consultancy Limited 62RFP for Selection of Bidder as Transmission Service Provider We hereby also agree and undertake to comply with Department of Expenditure, Ministry of Finance revised OM dated 23.02.2023 issued in suppression of Order (Public Procurement No 1) bearing File No. 6/18/2019-PPD dated 23.07.2020, Order (Public Procurement No 2) bearing File No. 6/18/2019-PPD dated 23.07.2020 and Order (Public Procurement No. 3) bearing File No. 6/18/2019-PPD, dated 24.07.2020, Office Memorandum (OM) No. F.18/37/2020-PPD dated 08.02.2021, OM No. F.12/1/2021- PPD(Pt.) dated 02.03.2021, OM No. F.7/10/2021-PPD dated 08.06.2021 and Order (Public Procurement No 4) bearing File No. F.7/10/2021-PPD dated 23.02.2023 as amended from time to time, regarding public procurement from a bidder of a country, which shares land border with India. 5. We hereby agree to comply with Ministry of Power order no. 25-11/6/2018 – PG dated 02.07.2020 as amended from time to time. 6. We are herewith submitting legally binding board resolution for the total equity requirement of the Project. 7. We hereby confirm that in accordance with Clause 2.1.4 of the RFP, we are herewith submitting legally binding undertaking supported by a board resolution from the …………………………..(Insert name of Technically Evaluated Entity and/or Financially Evaluated Entity or its Ultimate Parent Company, as the case may be) that all the equity investment obligations of ………….. (Insert name of the Bidding Company) shall be deemed to be equity investment obligations of the ………………… (Insert name of Technically Evaluated Entity and/or Financially Evaluated Entity or its Ultimate Parent Company, as the case may be) and in the event of any default by………………. (Insert name of the Bidding Company), the same shall be met by ………………. (Insert name of Technically Evaluated Entity and/or Financially Evaluated Entity or its Ultimate Parent Company, as the case may be). [Sl. No 7 to be inserted only in case the Bidder is a Bidding Company / Lead Member of a Consortium and has sought qualification on the basis of technical and financial capability of its Affiliate(s) and/or its Parent] 8. We confirm that there are no litigations or disputes against us, which materially affect our ability to fulfill our obligations with regard to the Project. 9. We hereby confirm that we shall continue to maintain compliance with Qualification Requirements till the execution of the Transmission Service Agreement. Further, in case we emerge as Selected Bidder for the Project, we shall continue to maintain compliance with Qualification Requirements till the COD of the Project. 10. We confirm that we have studied the provisions of relevant Indian laws and regulations required to enable us to build, own, operate and transfer the said Project and to prepare this Bid. 11. We hereby confirm that we shall abide unreservedly with BPC’s decision in the qualification process for selection of Qualified Bidder and further warrant that under no circumstances we shall challenge either the BPC’s decision or its right to make such decision at any time in the future. REC Power Development and Consultancy Limited 63RFP for Selection of Bidder as Transmission Service Provider 12. We confirm that the Bid shall remain valid for a period of one eighty (180) days from the Bid Deadline. 13. The details of contact person are furnished as under: Name: ……………………………………………… Designation: ……………………………………………… Name of the Company: ……………………………………………… Address of the Bidder: ……………………………………………… Phone Nos.: …………………………………. Fax Nos.: …………………………………. E-mail address: …………………………………. 14. Bid Bond We have enclosed a Bid Bond of Rupees ………………. Crores (Rs. …………….) only or US$ ............. (…………….US Dollars), in the form of bank guarantee no………………[Insert number of the Bank Guarantee] dated………….[Insert Date of the Bank Guarantee] as per your proforma (Annexure-14) from………………….[Insert name of bank providing Bid Bond] and valid up to ……………………………….in terms of Clause 2.11 of the RFP Or in the form of insurance surety bond no …….. [Insert number of the Insurance Surety Bond] dated ………….. [Insert Date of the Insurance Surety Bond] as per your proforma (Annexure- 14A) from ........................... [Insert name of Insurance Company providing Insurance Surety bond] and valid up to ……….. in terms of Clause 2.11 of the RFP or in the form of Payment on Order Instrument no. ……… [Insert number of the Instrument] dated …........ [Insert Date of the Instrument] as per your proforma (Annexure-14B) from ...................... [Insert name of company issuing Payment on Order Instrument] and valid up to ....................... in terms of Clause 2.11 of the RFP. 15. Acceptance We hereby unconditionally and irrevocably agree and accept that the decision made by the BPC on any matter regarding or arising out of the RFP shall be binding on us. We hereby expressly waive any and all claims in respect of Bid process. 16. Familiarity With Relevant Indian Laws & Regulations We confirm that we have studied the provisions of relevant Indian laws and regulations as required to enable us to submit this Bid and execute the RFP Project Documents (other than TSA), in the event of our selection as the TSP. We further undertake and agree that all such factors as mentioned in Clause 2.5.7 of RFP have been fully examined and considered while submitting the Bid. It is confirmed that our Bid is consistent with all the requirements of submission as stated in the RFP and subsequent communications from BPC. REC Power Development and Consultancy Limited 64RFP for Selection of Bidder as Transmission Service Provider The information submitted in our Bid is complete, strictly as per the requirements stipulated in the RFP and is correct to the best of our knowledge and understanding. We would be solely responsible for any errors or omissions in our Bid. We confirm that we have not taken any deviation so as to be deemed non-responsive with respect to the provisions stipulated at Clause 2.5.1, of this RFP. Thanking you, Yours sincerely, ………………………. (Name and Signature of the authorized signatory in whose name Power of Attorney/ Board Resolution as per Clause 2.5.2 is issued) Name: ……………………………………………… Designation: ……………………………………………… Address: ……………………………………………… Date: …………………………. Place: ………………………… Company Rubber Stamp REC Power Development and Consultancy Limited 65RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 2 - LETTER OF CONSENT FROM CONSORTIUM MEMBERS (On the letter head of each Member of the Consortium including Lead Member) Date: ………………………………… From: ………………………………… ………………………………… ………………………………… Tel. No.: ………………………………… Fax No.: ………………………………… E-mail address: ……………………………….. To, Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process. We, the undersigned Member of ……… (Insert name of the Bidding Consortium) have read, examined and understood the RFP document for the short-listing of Bidders as prospective TSP to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I) ” through tariff based competitive bidding process. We hereby confirm our concurrence with the Bid including in particular the Consortium Agreement submitted by …………. (Insert name of the Lead Member) in response to the RFP document. We hereby confirm our commitment to participate in the said Bidding Consortium and invest ……. % of the total equity requirement for the Project as per the terms of the Consortium Agreement dated ……… and board resolution for such investment commitment is enclosed herewith. We hereby confirm that in accordance with Clause 2.1.4 of the RFP, we are enclosing legally binding undertaking supported by a board resolution from the …………………………. (Insert name of Technically Evaluated Entity and / or Financially Evaluated Entity or its Ultimate Parent Company, as the case may be) that all the equity investment obligations of …………………. (Insert name of the Member) shall be deemed to be equity investment obligations of the ………………… (Insert name of Technically Evaluated Entity and / or Financially Evaluated Entity or its Ultimate Parent Company, as the case may be) and in the event of any default by………………. (Insert name of the Member), the same shall be met by………………. (Insert name of Technically Evaluated Entity and / or Financially Evaluated Entity or its Ultimate Parent Company, as the case may be). [Insert if applicable] REC Power Development and Consultancy Limited 66RFP for Selection of Bidder as Transmission Service Provider [To be inserted by the Lead Member only] We are also enclosing legally binding board resolution for the total equity requirement of the Project in case of any breach of any of the equity investment commitment by any of the Consortium Members, in line with the provisions of the Consortium Agreement dated ………. [Bidder to insert date of Consortium Agreement]. The details of contact person are furnished as under: Name: ……………………………………. Designation: ……………………………………. Name of the Company: ……………………………………. Address: ……………………………………. Phone Nos.: ……………………………………. Fax Nos.: ……………………………………. E-mail address: ……………………………………. Dated the ……. day of ……. of 20… Thanking you, Yours faithfully, ………………………………… (Signature) Name: …………………………. Designation: …………………………. (Signature, Name, Designation of Authorized Signatory of Consortium Member and Company's Seal) REC Power Development and Consultancy Limited 67RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 3 - FORMAT FOR EVIDENCE OF AUTHORIZED SIGNATORY’S AUTHORITY (POWER OF ATTORNEY) POWER OF ATTORNEY (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign companies submitting bids are required to follow the applicable law in their country) Know all men by these presents, We …………………………………………….(name and address of the registered office of the Bidder) do hereby constitute, appoint and authorize Mr./Ms…………………………………………………(name and residential address) who is presently employed with us and holding the position of ………………………………. as our attorney, to do in our name and on our behalf, all such acts, deeds and things necessary in connection with or incidental to our Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process in the country of India, including signing and submission of all documents related to the Bid, including, undertakings, letters, certificates, acceptances, clarifications, guarantees, etc., making representations to the BPC, and providing information / responses to the BPC, representing us in all matters before the BPC, and generally dealing with the BPC in all matters in connection with our Bid for the said Project till the completion of the bidding process in accordance with the RFP and signing of the Share Purchase Agreement by all the parties thereto. We hereby agree to ratify all acts, deeds and things lawfully done by our said attorney pursuant to this Power of Attorney and that all acts, deeds and things done by our aforesaid attorney shall and shall always be deemed to have been done by us. All the terms used herein but not defined shall have the meaning ascribed to such terms under the RFP. For …………………………. [Insert name of the Bidder on whose behalf PoA is executed] ………………….. (Signature) Name: ………………………. Designation: ………………………. Accepted ………..………… (Signature of the Attorney) Name: ……………………………. Designation: ...………………………….. Address: ............................................. ..................................................................... (Name, Designation and Address of the Attorney) REC Power Development and Consultancy Limited 68RFP for Selection of Bidder as Transmission Service Provider Specimen signatures of attorney attested by the Executant ………………………… (Signature of the Executant) ………………………….. (Signature of Notary Public) Place: ………………………… Date: ………………………… Notes: 1) To be executed by Bidding Company or the Lead Member, in the case of a Bidding Consortium, as the case maybe. 2) The mode of execution of the Power of Attorney should be in accordance with the procedure, if any, laid down by the applicable law and the charter documents of the executant(s) and when it is so required, the same should be under common seal of the executant affixed in accordance with the applicable procedure. Further, the person whose signatures are to be provided on the power of attorney shall be duly authorized by the executant(s) in this regard. 3) Also, wherever required, the executant(s) should submit for verification the extract of the charter documents and documents such as a Board resolution / power of attorney, in favour of the Person executing this power of attorney for delegation of power hereunder on behalf of the executant(s). 4) In case of foreign Bidders, refer to clause 2.5.6 (p) REC Power Development and Consultancy Limited 69RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 4 - FORMAT FOR POWER OF ATTORNEY TO BE PROVIDED BY EACH OF THE OTHER MEMBERS OF THE CONSORTIUM IN FAVOUR OF THE LEAD MEMBER POWER OF ATTORNEY (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign companies submitting bids are required to follow the applicable law in their country) KNOW ALL MEN BY THESE PRESENTS THAT M/s…………….……………., having its registered office at …………………………..…….., …..,..…and M/s ………………………….…. having its registered office at ……………………………….….. , (Insert names and registered offices of all Members of the Consortium), the Members of Consortium, have formed a Bidding Consortium named …………. (insert name of the Consortium) (hereinafter called the “Consortium”) vide Consortium Agreement dated……….……………….. and having agreed to appoint M/s…………………………….… as the Lead Member of the said Consortium do hereby constitute, nominate and appoint M/s…………….…………..a company incorporated under the laws of ……….………and having its Registered / Head Office at ……………………..……….as our duly constituted lawful Attorney (hereinafter called as “Lead Member”) which is one of the Members of the Consortium, to act as the Lead Member and our true and lawful attorney, to do in our name and on our behalf, all such acts, deeds and things necessary in connection with or incidental to submission of Consortium's Bid for the Project, including signing and submission of the Bid and all documents related to the Bid, including, undertakings, letters, certificates, acceptances, clarifications, guarantees, etc, making representations to the BPC, and providing information / responses to the BPC, representing us and the Consortium in all matters before the BPC, and generally dealing with the BPC in all matters in connection with our Bid for the said Project, till completion of the bidding process in accordance with the RFP and signing of the Share Purchase Agreement by all the parties thereto. It is expressly understood that in the event of the Consortium being selected as Successful Bidder, this Power of Attorney shall remain valid, binding and irrevocable until the Bidding Consortium achieves execution of all RFP Project Documents. We, as the Member of the Consortium, agree and undertake to ratify and confirm all whatsoever the said Attorney/Lead Member has done on behalf of the Consortium Members pursuant to this Power of Attorney and the same shall bind us and deemed to have been done by us. All the terms used herein but not defined shall have the meaning ascribed to such terms under the RFP. IN WITNESS WHEREOF M/s ………………………………………….……., as the Member of the Consortium have executed these presents on this……….. day of ........ For and on behalf of Consortium Member ………………………………. (Signature of the Authorized Signatory) REC Power Development and Consultancy Limited 70RFP for Selection of Bidder as Transmission Service Provider Name: …………………………… Designation: ..………………….... Place: …………………………… Date: …………………………….. Name: …………………………… Designation: ..………………….... Place: …………………………… Date: …………………………….. Accepted Specimen signatures of attorney attested ………………………. (Signature) ………………………… …………………………… (Signature of Notary Public) …………………………… (Name, Designation and Address of the Attorney) Place: ………………………… Date: …………………………. Notes: 1. The mode of execution of the power of attorney should be in accordance with the procedure, if any, laid down by the applicable law and the charter documents of the executant(s) and when it is so required, the same should be under common seal of the executant affixed in accordance with the applicable procedure. Further, the person whose signatures are to be provided on the power of attorney shall be duly authorized by the executant(s) in this regard. 2. Also, wherever required, the executant(s) should submit for verification the extract of the charter documents and documents such as a Board resolution / power of attorney, in favour of the Person executing this power of attorney for delegation of power hereunder on behalf of the executant(s). 3. In case of foreign Bidders, refer to clause 2.5.6 (p) REC Power Development and Consultancy Limited 71RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 5 - FORMAT FOR BIDDER’S COMPOSITION AND OWNERSHIP STRUCTURE 1. Corporate Details: Please provide the following information for the Bidder. If the Bidder is a Consortium, please provide this information for each Member including the Lead Member: a. Company’s Name, Address, and Nationality: Name: ………………………………………………… Address: ………………………………………………… ………………………………………………… ………………………………………………… Website Address: ……………………………………………….. Country of Origin: ………………………………………………… b. Year Organized: ……………………………………………….. c. Company's Business Activities: ……………………………………………. ......................................................................................................................... d. Status as a Bidder: i. Bidding Company ii. Lead Member of the Bidding Consortium iii. Member of the Bidding Consortium Note: tick the applicable serial number e. Company's Local Address in India (if applicable): …………………………………………………. …………………………………………………. …………………………………………………. f. Name of the Authorized Signatory: ............................................. g. Telephone Number: ………………………………………………. h. Email Address: ………………………………………………. i. Telefax Number: ………………………………………………. j. Please provide the following documents: i. Copy of the Memorandum and Articles of Association and certificate of incorporation or other equivalent organizational document (as applicable), including their amendments, certified by the Company Secretary as REC Power Development and Consultancy Limited 72RFP for Selection of Bidder as Transmission Service Provider Attachment 1 for Bidding Company / each Member of Bidding Consortium including Lead Member. ii. Authority letter (as per format for authorization given below) in favour of BPC from the Bidder/every Member of the Consortium authorizing BPC to seek reference from their respective bankers & others as Attachment 2 as per Clause 2.1.6 of the RFP. 2. Details of Ownership Structure: Equity holding of Bidding Company/ each Member of Bidding Consortium including Lead Member owning 10% or more of total paid up equity. Name of the Bidding Company / Consortium Member: ……………. Status of equity holding as on ………… Type and No. of Extent of Voting Name of the Equity Holder Shares owned Control (%) 1. ...................................................... 2. ...................................................... 3. ...................................................... 4. ...................................................... 5. ...................................................... 6. ...................................................... 7. ...................................................... 8. ...................................................... .... ...................................................... Notes: 1. The above table is to be filled in separately for each Consortium Member. 2. Status of equity holding should be provided not earlier than thirty (30) days prior to Bid Deadline. For and on behalf of Bidding Company / Lead Member of the Bidding Consortium M/s…………………………………………………. ………………………………….. (Signature of authorized representative) Name: ………………………………….. Designation: …………………………………… …………………………….. (Stamp) Date: …………………………… Place: …………………………… REC Power Development and Consultancy Limited 73RFP for Selection of Bidder as Transmission Service Provider FORMAT FOR AUTHORISATION (In case of Bidding Consortium, to be given separately by each Member) (On Non – judicial stamp paper duly attested by notary public. Foreign companies submitting bids are required to follow the applicable law in their country) The undersigned hereby authorize(s) and request(s) all our Bankers, including its subsidiaries and branches, any person, firm, corporation or authority to furnish pertinent information deemed necessary and requested by REC Power Development and Consultancy Limited to verify our Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission system for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process or regarding our project development experience, financial standing and general reputation. For and on behalf of M/s……………. (Insert Name of Bidding Company or Member of the Consortium) ................................. (Signature) Name of Authorized Signatory: ………………………………………………. (Signature and Name of the authorized signatory of the Company) Place: ………………………… Date: …………………… …………………………….. (Company rubber stamp/seal) …………………………………. (Signature of Notary Public) Place: ………………………… Date: …………………… REC Power Development and Consultancy Limited 74RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 6 - FORMAT FOR CONSORTIUM AGREEMENT (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign companies submitting bids are required to follow the applicable law in their country) THIS CONSORTIUM AGREEMENT executed on this....................... day of ..................Two thousand..................between M/s................................................................, a company incorporated under the laws of ...................................... and having its Registered Office at ................................ (hereinafter called the "Party 1”, which expression shall include its successors, executors and permitted assigns) and M/s..................................................................a Company incorporated under the laws of ......................................................... and having its Registered Office at ............................................................ (hereinafter called the "Party n", which expression shall include its successors, executors and permitted assigns) and for the purpose of submitting the Bid, acquisition of ……………… (Insert the name of SPV) (in case of award) and entering into other Agreement(s) as specified in the RFP (hereinafter referred to as “Agreements”) as may be entered into with the Nodal Agency. WHEREAS, the BPC had invited Bid in response to RFP issued to ……………………………… (insert the name of purchaser of RFP) for selection of the bidder as the Transmission Service Provider to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” AND WHEREAS, Clause 2.2.4 of the RFP document stipulates that the Bidders qualifying on the strength of a Bidding Consortium will have to submit a legally enforceable Consortium Agreement in a format specified in the RFP document wherein the Consortium Members have to commit equity of a specific percentage in the Project. AND WHEREAS, Clause 2.2.4 of the RFP document also stipulates that the Bidding Consortium shall provide along with the Bid, a Consortium Agreement as per prescribed format whereby the Consortium Members undertake to be liable for raising the required funds for its respective equity investment commitment as specified in Consortium Agreement. NOW THEREFORE, THIS INDENTURE WITNESSTH AS UNDER: In consideration of the above premises and agreement all the parties in this Consortium do hereby mutually agree as follows: 1. In consideration of the selection of the Consortium as the selected bidder by the BPC, we the Members of the Consortium and parties to the Consortium Agreement do hereby unequivocally agree that M/s........................................................... (Insert name of the Lead Member), shall act as the Lead Member as defined in the RFP for self and agent for and on behalf of ………., .................., .............., ............. (the names of all the other Members of the Consortium to be filled in here). 2. The Lead Member is hereby authorized by the Members of Consortium and parties to the Consortium Agreement to bind the Consortium and receive instructions for and on behalf of the Members. REC Power Development and Consultancy Limited 75RFP for Selection of Bidder as Transmission Service Provider 3. Notwithstanding anything contrary contained in this Consortium Agreement, the Lead Member shall always be liable for the equity investment obligations of all the Consortium Members, i.e., for both its own equity contribution as well as the equity contribution of other Members. 4. The Lead Member shall be liable and responsible for ensuring the individual and collective commitment of each of the Members of the Consortium in discharging all their respective equity obligations. Each Consortium Member further undertakes to be individually liable for the performance of its part of the obligations without in any way limiting the scope of collective liability envisaged in this agreement. 5. Subject to the terms of this agreement, the share of each Member of the Consortium in the “issued equity share capital of the project company” shall be in the following proportion: (if applicable) Percentage of equity holding in Name the Project Party 1 ……….. ……….. ……….. Party n ……….. Total 100% [Note: The percentage equity holding for any Consortium Member in the Project cannot be zero in the above table] 6. The Lead Member shall inter alia undertake full responsibility for liaising with lenders and mobilizing debt resources for the Project and achieving financial closure. 7. In case of any breach of any of the equity investment commitment by any of the Consortium Members, the Lead Member shall be liable for the consequences thereof. 8. Except as specified in the Agreement, it is agreed that sharing of responsibilities as aforesaid and equity investment obligations thereto shall not in any way be a limitation of responsibility of the Lead Member under these presents. 9. It is further specifically agreed that the financial liability for equity contribution of Lead Member shall, not be limited in any way so as to restrict or limit its liabilities. The Lead Member shall be liable irrespective of their scope of work or financial commitments. 10. It is expressly understood and agreed between the Members that the responsibilities and obligations of each of the Members shall be as delineated as annexed hereto as Appendix- I, forming integral part of this Agreement. It is further agreed by the Members that the above sharing of responsibilities and obligations shall not in any way be a limitation of joint and several responsibilities and liabilities of the Members, with regards to all matters relating to the Project. 11. It is clearly agreed that the Lead Member shall ensure performance under the Agreements and if one or more Consortium Members fail to perform its /their respective obligations under the Agreement(s), the same shall be deemed to be a default by all the Consortium Members. REC Power Development and Consultancy Limited 76RFP for Selection of Bidder as Transmission Service Provider 12. This Consortium Agreement shall be construed and interpreted in accordance with the Laws of India and courts at Delhi alone shall have the exclusive jurisdiction in all matters relating thereto and arising there under. 13. It is hereby agreed that, the Lead Member shall furnish the bid bond, as stipulated in the RFP, on behalf of the Consortium Members. 14. It is hereby agreed that in case of selection of Bidding Consortium as the selected bidder, the parties to this Consortium Agreement do hereby agree that they shall furnish the contract performance guarantee on behalf of the TSP in favor of the Nodal Agency, as stipulated in the RFP and Transmission Service Agreement. 15. It is further expressly agreed that the Consortium Agreement shall be irrevocable and shall form an integral part of the RFP Project Document and shall remain valid till the execution of the Share Purchase Agreement, unless expressly agreed to the contrary by the Nodal Agency. Over the term of the Transmission Service Agreement, Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations as amended from time to time shall apply on the Consortium Members. 16. The Lead Member is authorized and shall be fully responsible for the accuracy and veracity of the representations and information submitted by the Consortium Members respectively from time to time in response to the RFP and for the purposes of the Project. 17. It is hereby expressly agreed between the parties to this Consortium Agreement that neither party shall assign or delegate its rights, duties or obligations under this Agreement except with the prior written consent of the Nodal Agency. THIS CONSORTIUM AGREEMENT: a. has been duly executed and delivered on behalf of each party hereto and constitutes the legal, valid, binding and enforceable obligation of each such party, b. sets forth the entire understanding of the parties hereto with respect to the subject matter hereof; c. may not be amended or modified except in writing signed by each of the parties and with prior written consent of the Nodal Agency. IN WITNESS WHEREOF, the parties to the Consortium Agreement have, through their authorized representatives, executed these present on the Day, Month and Year first mentioned above. For and on behalf of Consortium Member 1 (Party 1) M/s…………………………. .................................................... (Signature of authorized signatory) REC Power Development and Consultancy Limited 77RFP for Selection of Bidder as Transmission Service Provider Name: …………………………. Designation: ............…………………. Place: ……………………………….. Date: ………………………………… For and on behalf of Consortium Member n (Party n) M/s…………………………. .................................................... (Signature of authorized signatory) Name: …………………………… Designation: ..........…………………... Place: ………………………………. Date: ………………………………... Attested: ……………………………….. (Signature) (Notary Public) Place: ………………………. Date: ………………………. Note: In case of foreign Bidders, refer to clause 2.5.6 (p) REC Power Development and Consultancy Limited 78RFP for Selection of Bidder as Transmission Service Provider Appendix 1 to the Consortium Agreement: Name of the Consortium Responsibilities under the Consortium Agreement Member M/s …………… (Party 1) M/s …………… M/s …………… (Party n) REC Power Development and Consultancy Limited 79RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 7A - FORMAT FOR QUALIFICATION REQUIREMENT A. NET WORTH To, Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process 1. [Note: Applicable in case of Bidding Company] We certify that the Financially Evaluated Entity(ies) had a Networth of Rs. ……… Crore or equivalent USD* computed as per instructions in this RFP based on unconsolidated audited annual accounts (refer Note-2 below) of any of the last three (3) financial years as provided in Clause 2.2.3, immediately preceding the Bid Deadline. Also, the Networth of any of the last three (3) financial years is not negative. Financial Name of Financially Relationship with Bidding Networth Year Evaluated Entity(ies) Company** (Rs. Crore) 1. ……………………….. 2. ……………………….. 3. ……………………….. …. Total Networth *Equivalent USD shall be calculated as per provisions of Clause 3.4.1. ** The column for “Relationship with Bidding Company” is to be filled in only in case financial capability of Parent/Affiliate has been used for meeting Qualification Requirements. 2. [Note: Applicable in case of Bidding Consortium] We certify that the Financially Evaluated Entity(ies) had a minimum Networth of Rs. …….. Crore or equivalent USD* computed as per instructions in the RFP and based on unconsolidated audited annual accounts (refer Note-2 below) of any of the last three (3) financial years as provided in Clause 2.2.3, immediately preceding the Bid Deadline. Also, the Networth of any of the last three (3) financial years is not negative. REC Power Development and Consultancy Limited 80RFP for Selection of Bidder as Transmission Service Provider Networth Requirement to Whether the Equity Networth of be met by Member Name of Consortium Commitment Member Member in meets the Member in the Project (Rs. Crore) proportion to the Networth (%) Equity Requirement Commitment (Rs. Crore) (4 )= (2 x Total (3) Networth (1) (2) (As per (5) requirement for table below) the Project ) 1. …………… Yes / No 2. …………… Yes / No .. Yes / No Total Networth for financial requirement Member – I (Lead Member) [Note: Similar particulars for each Member of the Consortium is to be furnished, duly certified by the Member’s Statutory Auditors] i. Name of Member: ............................................ ii. Total Networth requirement: Rs ……………… Crore iii. Percentage of equity commitment for the Project by the Member: …………% iv. Networth requirement for the Member***: Rs. ………………. Crore v. Financial year considered for the Member: …………………………. Name of Financially Evaluated Relationship** with Financial Networth Entity(ies) Member of Consortium Year (Rs. Crore) 1. …………………………. 2. …………………………. 3. …………………………. Total Networth * Equivalent USD shall be calculated as per provisions of Clause 3.4.1; ** The column for “Relationship with Member of Consortium” is to be filled in only in case the financial capability of Parent / Affiliate has been used for meeting Qualification Requirements; *** Networth requirement to be met by Member should be in proportion to the equity commitment of the Member for the Project. REC Power Development and Consultancy Limited 81RFP for Selection of Bidder as Transmission Service Provider Yours faithfully ……………………………………… (Signature and name of the authorized signatory of the Company and Stamp) Name: …………………………………. Date: …………………………………. Place: …………………………………. ………………………………………… (Signature and Stamp of statutory Auditors of Bidding Company / each Member of Consortium) Name: …………………………………. Date: …………………………………. Place: …………………………………. Date: …………………………………. Notes: 1. Along with the above format, in a separate sheet, please provide details of computation of Networth of last three (3) financial years duly certified by Statutory Auditor. 2. Audited consolidated annual accounts of the Bidder may be used for the purpose of financial criteria provided the Bidder has at least 26% equity in each company whose accounts are merged in the audited consolidated accounts and provided further that the financial capability of such companies (of which accounts are being merged in the consolidated accounts) shall not be considered again for the purpose of evaluation of the Bid. 3. In case Bidder or a Member of Consortium takes recourse to its Parent/Affiliate for meeting technical / financial requirements, then the financial years considered for such purpose should be same for the Bidder / Member of Consortium and their respective Parent / Affiliate. REC Power Development and Consultancy Limited 82RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 7B - FORMAT FOR TECHNICAL REQUIREMENT To, Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process 1. To be used by Bidder using the development experience in infrastructure sector We certify that M/s. ………….. (Insert name of Technically Evaluated Entity(ies)) have experience of development of projects in the Infrastructure sector in the last five (5) years whose aggregate capital expenditure is Rs. ………. Crore or equivalent USD*. We further certify that the capital expenditure of any single project considered for meeting the technical Qualification Requirement is not less than Rs. …… Crore or equivalent USD*. For this purpose, capital expenditure incurred on projects which have been either wholly completed / commissioned or partly completed projects put under commercial operation and for which operation has commenced till at least seven (7) days prior to the Bid Deadline has been considered. The project(s) considered for the purpose of technical experience (as per table given below) have been executed and owned to the extent as indicated in the table below (to be atleast twenty – six percent (26%)) by the Bidding Company / Lead Member of the Consortium / our Parent / our Affiliate(s) [strike off whichever is not applicable] on operation of the projects. This technical requirement has been calculated as per the instructions provided in the RFP on the basis of following projects: Name of Nature Date of Date of Company (which Percentage of Financial Completion / has executed the Equity Relationship** Project Closure Commissioning Project project at (3)) Relevant Holding of with Bidding Project (BOOT, of the / Commercial cost whose technical Infrastructure Company Company / name BOT, Project Operation of (Rs. capability has sector at (1) in Lead Member BOOM, (in DD / partly Crore) been used for Completed DBFOT MM / completed Qualification project(s) etc.) YYYY) projects Requirement (1) (2) (3) (4) (5) (6) (7) (8) (9) ………………… ………. (Project 1) ………………… ………. Total (Rs. Crore) REC Power Development and Consultancy Limited 83RFP for Selection of Bidder as Transmission Service Provider * Equivalent USD shall be calculated as per provisions of Clause ____ ** The column for “Relationship with Bidding Company / Lead Member” is to be filled in only in case technical capability of Parent/Affiliate has been used for meeting Qualification Requirements. We further certify that the Company(ies) as indicated in column (1) of the above table, whose technical capability has / have been used for meeting the qualification requirement, has / have held shareholding respectively of atleast twenty – six percent (26%) from the date of financial closure till the date of commissioning / completion of the above project(s). 2. To be used by Bidder using construction experience in infrastructure sector. We certify that M/s. ………….. (Insert name of Technically Evaluated Entity(ies)) have received aggregate payments not less than Rs. ……. Crore or equivalent USD (calculated as per provisions in Clause 3.4.1) from its client(s) for construction works fully completed during the last 5(five) financial years. We further certify that the payment received from each project shall not be less than Rs. ……. Crore or equivalent USD (calculated as per provisions in Clause 3.4.1). For this purpose, payments received on projects that have been commissioned/completed at least seven (7) days prior to the Bid Deadline shall be considered. Further only the payments (gross) actually received, during such 5 (five) financial years shall qualify for purposes of computing the technical capacity. We also confirm that construction works does not include cost of land supply of goods or equipment except when such goods or equipment form part of a turn-key construction contract/ EPC contract for the project. This technical requirement has been calculated as per the instructions provided in the RFP on the basis of following projects: Name of Company (which has executed the Nature of project at (3)) Relationship** Project Relevant Date of Date of Payment with Bidding Project award of received whose technical (EPC, Infrastructure Completion / Company / Lead name contract (in (Rs. capability has Member Turnkey sector dd/mm/yy) Commissioning Crore) been used for etc) Qualification Requirement (1) (2) (3) (4) (5) (6) (7) (8) ………………… ………. Project 1 ………………… ………. ………………… ………. Total (Rs. Crore) Yours faithfully REC Power Development and Consultancy Limited 84RFP for Selection of Bidder as Transmission Service Provider …………………………………………….. (Signature and name of the authorized signatory of the Company and stamp) Name: ………………………………….. Date: ………………………………….. Place: ………………………………….. ………………………………………. (Signature and Stamp of statutory Auditors of Bidding Company/ Lead Member of Consortium) Name: ……………………………….. Date: ……………………………….. Place: ……………………………….. Date: …………………. Notes: 1. Along with the above format, in a separate sheet, please provide details of computation of capital expenditure of projects duly certified by Statutory Auditor of the project company. In addition, the Statutory Auditor of the project company should also certify that the capital expenditure of projects commissioned or completed 7 days prior to Bid Deadline has been capitalized in the books of accounts. Additionally, in case construction experience is used, a certificate(s) from the statutory auditors stating the payments received and the concerned client(s) stating the works commissioned during the past 5 years in respect of the projects specified above. In case a particular job/ contract has been jointly executed by the Bidder (as part of a consortium), it should further support its claim for the share in work done for that particular job/ contract by producing a certificate from its statutory auditor or the client. 2. In case the accounts for the financial year in which the project claimed for meeting qualification requirement has been commissioned are not audited, the Bidder shall give declaration in this regard duly certified by its statutory auditor. In such a case, Bidder shall provide details of computation of capital expenditure of such project(s) duly certified by Statutory Auditor of the project company and the Statutory Auditor of the project company should also certify that the capital expenditure of projects commissioned or completed shall be capitalized in the books of accounts upon finalization. 3. The unconsolidated audited annual accounts of both the TEE and the Bidding Company / Lead Member for the respective financial years (financial years in which financial closure was achieved to the financial year in which the said project was completed / commissioned) should be submitted. REC Power Development and Consultancy Limited 85RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 7C - FORMAT FOR TECHNICAL & FINANCIAL REQUIREMENT – RELATIONSHIP & DETAILS OF EQUITY SHAREHOLDING [To be filled by Bidding Company / each Member of the Bidding Consortium including Lead Member if credentials of Parent and / or Affiliates have been used by them] To, Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Bid for selection of Bidder as Transmission Service Provider to establish Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process We certify that M/s. …………. (insert name of the Bidding Company / Consortium Members) have considered the technical and financial capability of its Parent and / or Affiliates, for the purpose of meeting Qualification Requirements as per the instructions provided in the RFP. The name of Parent and / or Affiliate, nature of relationship(s) with such Parent and / or Affiliate and details of equity holding are as follows: Name of Type of credentials Relationship with Details of equity Company whose considered Bidding Company / shareholding credentials (technical and / or Consortium Member (refer notes below) considered financial) (Parent / Affiliate) Company 1 ……………. ……………. ……………. …………….. NOTES: i. In case of Parent, the equity holding of the Parent in the Bidding Company / Member of the Bidding Consortium, including the Lead Member of the Consortium, need to be specified. ii. In case of Affiliate under direct control of Bidder, the equity holding of the Bidding Company / Member of the Bidding Consortium, including the Lead Member of the Consortium in the Affiliate, needs to be specified. iii. In case of Affiliate under common control of Parent, the equity holding of the Parent in the Affiliate of the Bidding Company / Member of the Bidding Consortium, including the Lead Member of the Consortium, needs to be specified. REC Power Development and Consultancy Limited 86RFP for Selection of Bidder as Transmission Service Provider iv. Relationship of Parent / Affiliate with Bidding Company / Member of Consortium to be at the most seven (7) days prior to the Bid Deadline (as per Clause 2.1.4 of RFP) Yours faithfully ……………………………… (Signature and name of the authorized signatory of the Company and stamp) Name: ………………………… Date: ………………………… Place: ………………………… …………………………………… (Signature and Stamp of statutory Auditors of Bidding Company / each Member of Bidding Consortium) Name: …………………………….. Date: …………………………….. Place: …………………………….. REC Power Development and Consultancy Limited 87RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 7D - ADDITIONAL INFORMATION FOR VERIFICATION OF FINANCIAL AND TECHNICAL CAPABILITIES OF BIDDERS. …………………………………….………………………………. (Name of Bidder (Bidding Company/ Bidding Consortium or Technically/Financially Evaluated Entity(ies)) (Note: In case of Consortium, details to be filled in by Lead Member for each Member of the Consortium including the Lead Member and in case of the qualification requirements of Technically / Financially Evaluated Entity(ies) being used, to be filled by each of such entity(ies) i. Financial capability (Attachment 1): 1. Bidders shall attach unconsolidated / consolidated audited annual accounts, statements, as the case may be, (refer Clause 2.1.3) for the last three (3) financial years as Attachment 1. Such unconsolidated audited annual accounts shall include a Balance Sheet, Profit and Loss Account, Auditors Report and profit appropriation account. ii. Technical capability (Attachment 2): a. This attachment shall include details of projects completed/commissioned or partly completed projects for which commercial operation has commenced to be considered for the purpose of meeting Qualification Requirements. 1. To be used by Bidder using development experience in infrastructure sector Particulars Year 1 Year 2 Year 3 Year 4 Year 5 Name(s) of project(s) from Infrastructure sectors Location(s) including country(s) where project was set up Nature of Project Voltage level (if any) Capital cost of project(s) Rs. in Crore *Status of the project % of equity owned in the project(s) *Note 1: Date of completion/commissioning/commercial operation to be mentioned Note 2: For each project listed in the table, the Bidder shall furnish an executive summary including the following information:  Project model, i.e., BOO, BOOT, BOOM; REC Power Development and Consultancy Limited 88RFP for Selection of Bidder as Transmission Service Provider  Debt financing and equity raised and provided by Bidder/Bidder’s Parent/Bidder’s Affiliate for the project, including names of lenders and investors;  Size and type of installation;  Technical data/information on major equipment installed  Description of role performed by the Bidder/Bidder’s Parent/Bidder’s Affiliate on the project  Clearances taken by the Bidder/Bidder’s Parent/Bidder’s Affiliate including but limited to right-of-way (RoW), forest clearance and other statutory / Govt. clearances.  Cost data (breakdown of major components)  Name of EPC and/or other major contractor  Construction time for the project  Names, addresses and contact numbers of owners of the projects  Operating reliability over the past five (5) years or since date of commercial operation  Operating environmental compliance history  Names of supervisory entities or consultant, if any  Date of commercial operation  Total duration of operation 2. To be used by Bidder using construction experience in infrastructure sector Particulars Year 1 Year 2 Year 3 Year 4 Year 5 Name(s) of project(s) from Infrastructure sectors Location(s) including country(s) where project was set up Nature of Project Voltage level (if any) Revenue received Rs. in Crore *Status of the project % of equity owned in the project(s) *Note 1: Date of completion/commissioning/commercial operation to be mentioned Note 2: For each project listed in the table, the Bidder shall furnish an executive summary including the following information:  Project model, i.e., EPC, Turnkey;  Size and type of installation;  Technical data/information on major equipment installed  Description of role performed by the Bidder/Bidder’s Parent/Bidder’s Affiliate on the project  Cost data (breakdown of major components)  Name of sub-contractor  Construction time for the project  Names, addresses and contact numbers of owners of the projects REC Power Development and Consultancy Limited 89RFP for Selection of Bidder as Transmission Service Provider  Operating reliability over the past five (5) years or since date of commercial operation  Operating environmental compliance history  Names of supervisory entities or consultant, if any  Date of commercial operation  Total duration of operation iii. Attachment-3: a. For each project listed in Attachment 2 above, certificates of final acceptance and/or certificates of good operating performance duly issued by owners for the project and the same shall be certified as true by authorized signatory of the Bidding Company or the Lead Member of Consortium). In case the project listed in Attachment 2 is under BOOT / DBFOT mechanism, the certificates of final acceptance and/or certificates of good operating performance must be issued by the authority / independent engineer of the project as defined in the respective project agreement. For and on behalf of Bidding Company/Consortium M/s……………………………………………. ……………………………………. (Signature of authorized signatory) Name: …………………………………… Designation: …………………………………… Date: …………………………………… Place: …………………………………… REC Power Development and Consultancy Limited 90RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 8 -UNDERTAKING AND DETAILS OF EQUITY INVESTMENT Format 1: Bidders' Undertakings [On the Letter Head of the Bidding Company/Lead Member of Bidding Consortium] Date: .............................. To, Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Bidders' Undertakings in respect of Bid for selection of Bidder as TSP to establish Inter- State transmission system for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” We hereby undertake on our own behalf and on behalf of the TSP, that if selected as the Successful Bidder for the Project: 1. The Project shall comply with all the relevant electricity laws, codes, regulations, standards and Prudent Utility Practices, environment laws and relevant technical, operational and safety standards, and we shall execute any agreements that may be required to be executed as per law in this regard. 2. We confirm that the Project shall also comply with the standards and codes as per Clause 1.6.1.2 of the RFP and the TSP shall comply with the provisions contained in the Central Electricity Regulatory Commission Grant of Connectivity, Long-term Access and Medium-term Open Access in inter-state Transmission and related matters Open Access) Regulations, 2009. 3. We give our unconditional acceptance to the RFP dated 03.02.2026 issued by the BPC and the RFP Project Documents, as amended, and undertake to ensure that the TSP shall execute all the RFP Project Documents, as per the provisions of this RFP. 4. We have submitted the Bid on the terms and conditions contained in the RFP and the RFP Project Documents. Further, the Financial Bid submitted by us is strictly as per the format provided in Annexure 21 of the RFP, without mentioning any deviations, conditions, assumptions or notes in the said Annexure. 5. Our Bid is valid up to the period required under Clause 2.8 of the RFP. 6. Our Bid has been duly signed by authorized signatory and stamped in the manner and to the extent indicated in this RFP and the power of attorney / Board resolution in requisite format as per RFP has been enclosed with this undertaking. REC Power Development and Consultancy Limited 91RFP for Selection of Bidder as Transmission Service Provider 7. We have assumed that if we are selected as the Successful Bidder, the provisions of the Consortium Agreement, to the extent and only in relation to equity lock in and our liability thereof shall get modified to give effect to the provisions of Clause 2.5.8 of this RFP and Article 18.1 of the Transmission Service Agreement. (Note: This is applicable only in case of a Bidding Consortium) 8. We confirm that our Bid meets the Scheduled COD of each transmission Element and the Project as specified below: Sl. No. Name of the Scheduled % of Quoted Element(s) Transmission Element COD as per Transmission which are pre- Gazette Charges required for Notification recoverable declaring the on Scheduled commercial COD of the operation Element of (COD) of the the Project respective Element 1. Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) GIS substation with Element at Sl. 1x330 MVAr (765 kV) No. 2, 3, 4, 5, bus reactor with space 6, 7 & 8 provision for establishment of 220 kV switchyard 2. ± 300 MVAr STATCOM with 2x125 MVAr MSC at 30 months 100 Element at Sl. Pendurthi (Vizag) GIS No. 1, 3, 4, 5, with control switching 6, 7 & 8 arrangement for proposed 1x330 MVAr bus reactor 3. Pendurthi (Vizag) – Srikakulam 765 kV D/c line with 330 Element at Sl. MVAr SLR No. 1, 2, 4, 5, (convertible) at 6, 7 & 8 Srikakulam end on both circuits REC Power Development and Consultancy Limited 92RFP for Selection of Bidder as Transmission Service Provider Sl. No. Name of the Scheduled % of Quoted Element(s) Transmission Element COD as per Transmission which are pre- Gazette Charges required for Notification recoverable declaring the on Scheduled commercial COD of the operation Element of (COD) of the the Project respective Element 4. LILO of Kalpakka – Element at Sl. Maradam 400 kV No. 1, 2, 3, 5, (quad) D/c line at 6, 7 & 8 Pendurthi 5. Establishment of 3x1500 MVA, 765/400 kV Khammam-II substation with 1x330 Element at Sl. MVAr (765 kV) bus No. 1, 2, 3, 4, reactor with space 6, 7 & 8 provision for establishment of 220 kV switchyard 6. Khammam-II – Element at Sl. Warangal New 765 kV No. 1, 2, 3, 4, 5 D/c line ,7 & 8 7. Khammam-II – Pendurthi (Vizag) 765 Element at Sl. kV D/c line with 330 No. 1, 2, 3, 4, MVAr SLR 5, 6 & 8 (convertible) at both ends on both circuits 8. Khammam-II – Element at Sl. Khammam (existing) No. 1, 2, 3, 4, 400 kV (quad) D/c line 5, 6 & 7 We agree that the payment of Transmission Charges for any Element irrespective of its successful commissioning on or before its Scheduled COD shall only be considered after the successful commissioning of Element(s) which are pre - required for declaring the commercial operation of such Element as mentioned in the above table. Scheduled COD for the Project: 30 months. 9. We confirm that our Financial Bid conforms to all the conditions mentioned in this RFP, and in particular, we confirm that: REC Power Development and Consultancy Limited 93RFP for Selection of Bidder as Transmission Service Provider a. Financial Bid in the prescribed format of Annexure 21 has been submitted duly signed by the authorized signatory. b. Financial Bid is unconditional. c. Only one Financial Bid has been submitted. 10. We have neither made any statement nor provided any information in this Bid, which to the best of our knowledge is materially inaccurate or misleading. Further, all the confirmations, declarations and representations made in our Bid are true and accurate. In case this is found to be incorrect after our acquisition of ……………… (Insert the name of SPV), pursuant to our selection as Selected Bidder, we agree that the same would be treated as a TSP's Event of Default under Transmission Service Agreement, and relevant provisions of Transmission Service Agreement shall apply. 11. We confirm that there are no litigations or other disputes against us which materially affect our ability to fulfill our obligations with regard to the Project as per the terms of RFP Project Documents. 12. Power of attorney/ Board resolution as per Clause 2.5.2 is enclosed. Signature and name of the authorized signatory of the Company and stamp of Bidding Company or Lead member of Consortium Note: 1. In case of foreign Bidders, refer to clause 2.5.6 (p) Format 2: Details of equity investment in Project 1.1.a Name of the Bidding Company/ Bidding Consortium: 1.1.b Name of the Lead Member in the case of a Bidding Consortium: 1.2 Investment details of the Bidding Company/Member of the Bidding Consortium investing in ……………… (Insert the name of SPV) as per Clause 2.5.8.2. Name of the Name of the Relationship Bidding Company investing with Bidding % of equity Company/ in the equity of the Company participation in the S. No. Member in ……………… /Member of the ……………… (Insert case of a (Insert the name of Bidding the name of SPV) Bidding SPV) Consortium Consortium (1) (2) (3) (4) (5) TOTAL 100% * In case the Bidder proposes to invest through its Affiliate(s) / Parent Company / Ultimate Parent Company, the Bidder shall declare shareholding pattern of such Affiliate(s) / Parent Company / REC Power Development and Consultancy Limited 94RFP for Selection of Bidder as Transmission Service Provider Ultimate Parent Company and provide documentary evidence to demonstrate relationship between the Bidder and the Affiliate(s) / Parent Company / Ultimate Parent Company. These documentary evidences could be, but not limited to, demat account statement(s) / Registrar of Companies' (ROC) certification / share registry book, etc duly certified by Company Secretary. Members of the Consortium or the Bidding Company making investment in the equity of the ……………… (Insert the name of SPV) themselves to fill in their own names in the column (3) Signature and Name of authorized signatory in whose name power of attorney has been issued Signature of authorized signatory Name: …………………………………. Designation: …………………………... Date……………………………………. Company rubber stamp REC Power Development and Consultancy Limited 95RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 9 -AUTHORISATION FROM PARENT / AFFILIATE OF BIDDING COMPANY / MEMBER OF BIDDING CONSORTIUM WHOSE TECHNICAL / FINANCIAL CAPABILITY HAS BEEN USED BY THE BIDDING COMPANY / MEMBER OF BIDDING CONSORTIUM. [On the Letter Head of the Parent /Affiliate] Name: ……………………………………………………………………. Full Address: ……………………………………………………………. Telephone No.: …………………………………………………………... E-mail address: …………………………………………………………... Fax / No.: ………………………………………………………………… To Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Dear Sir, Sub: Authorization for use of Technical / Financial Capability of M/s………. (Insert name of Parent / Affiliate) by M/s …….. (Insert name of Bidding Company / Member of Bidding Consortium). We refer to the RFP dated 03.02.2026 (‘RFP’) issued by you for selection of Bidder as Transmission Service Provider for establishing the Inter-State Transmission System for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” We confirm that M/s. ………. (Insert name of Bidding Company/ Consortium Member) has been authorized by us to use our technical and/or financial capability [strikeout whichever is not applicable] for meeting the Qualification Requirements for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” We have carefully read and examined in detail the RFP including in particular, Clause 2.1.4 of the RFP, and we are also submitting legally binding undertaking supported by a board resolution that all the equity investment obligations of M/s……………….…. (Insert Name of Bidding Company / Consortium Member), shall be deemed to be our equity investment obligations and in the event of any default the same shall be met by us. For and on behalf of M/s……………. (Insert Name of Parent / Affiliate) …………………………………… (Signature and Name of the authorized signatory of the Company and stamp) REC Power Development and Consultancy Limited 96RFP for Selection of Bidder as Transmission Service Provider Name: ………………………………………. Date: ………………………………………. Place: ………………………………………. Notes: 1. The above undertaking can be furnished by Ultimate Parent of Technically Evaluated Entity or Financially Evaluated Entity, as the case maybe, if legally binding undertaking is also furnished by the Ultimate Parent on behalf of such Financially Evaluated Entity/Technically Evaluated Entity. REC Power Development and Consultancy Limited 97RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 10- FORMAT OF UNDERTAKING BY TECHNICALLY / FINANCIALLY EVALUATED ENTITY / ULTIMATE PARENT COMPANY [On the Letter Head of the Technically / Financially Evaluated Entity / Ultimate Parent Company] Name: ……………………………………………………. Full Address: …………………………………………… Telephone No.: ………………………………………… E-mail address: ………………………………………… Fax/No.: ……………………………………………….. To: Chief Executive Officer, REC Power Development and Consultancy Limited (A wholly owned subsidiary of REC Limited) REC Corporate Head Quarter, D Block, Plot No. I – 4, Sec – 29 Gurugram – 122 001 Sub: Undertaking for equity investment Dear Sir, We refer to the Request for Proposal dated 03.02.2026 ('RFP') issued by you regarding setting up of Inter-State transmission system for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” Project on build, own, operate and transfer basis. We have carefully read and examined in detail the RFP and the RFP Project Documents, including in particular, Clause 2.1.4 of the RFP and Clauses 2.5.2 and 2.5.8 of the RFP, regarding submission of an undertaking regarding the investment in the equity share capital of ……………… (Insert the name of SPV) and provisions for minimum equity holding and equity lock-in. We have also noted the amount of the equity investment required to be made in ……………… (Insert the name of SPV) by the …………………………………………………. [Insert the name of the Bidder or the Consortium Member] for the Project. In view of the above, we hereby undertake to you and confirm that in the event of failure of ……………………[Insert the name of the Bidder or the Consortium Member] to invest in full or in part, in the equity share capital of ……………… (Insert the name of SPV) as specified in the Bid, we shall invest the said amount not invested by……………………………………..[Insert the name of the Bidder or the Consortium Member] in ……………… (Insert the name of SPV) by purchase of existing shares or subscribing to the new shares of ……………… (Insert the name of SPV), as stipulated by you. We have attached hereto a certified true copy of the Board resolution whereby the Board of Directors of our Company has approved issue of this Undertaking by the Company. REC Power Development and Consultancy Limited 98RFP for Selection of Bidder as Transmission Service Provider All the terms used herein but not defined, shall have the meaning as ascribed to the said terms under the RFP. Certified as true. …………………….. (Signature and Name of the authorized signatory of the Company and stamp) Note: 1. Wherever required, extract of the charter documents and documents such as a Board resolution should be submitted for verification. REC Power Development and Consultancy Limited 99RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 11 - FORMATS FOR BOARD RESOLUTIONS Format 1 Format of the Board resolution for the Bidding Company / each Member of the Consortium / investing Affiliate / Parent Company / Ultimate Parent Company, where applicable [Reference Clause 2.5.2 of the RFP and the illustrations in Annexure 11A] [Note: The following resolution no.1 needs to be passed by the Boards of each of the entity/(ies) making equity investment] The Board, after discussion, at the duly convened Meeting on ………………….. [Insert date], with the consent of all the Directors present and in compliance of the provisions of the Companies Act, 1956/2013, passed the following Resolution: 1. RESOLVED THAT pursuant to the provisions of the Companies Act, 1956 / Companies Act 2013 (as the case may be) and compliance thereof and as permitted under the Memorandum and Articles of Association of the company, approval of the Board be and is hereby accorded for investment of……….% (……per cent) of the total equity share capital of ……………… (Insert the name of SPV) representing the entire amount proposed to be invested by the company for the transmission system for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)”, partly by acquisition of the existing equity shares from .......................[Insert the name of the BPC] and / or partly by subscribing to the new equity shares, as per the terms of the RFP. [Note: Equity investment obligations by the Bidding Company/each Member of the Bidding Consortium/investing Affiliate or Parent or Ultimate Parent should add up to 100%.] [Note: In the event the Bidder is a Bidding Consortium, the following Board resolution no. 2 also needs to be passed by the Lead Member of the Bidding Consortium] 2. RESOLVED THAT approval of the Board be and is hereby accorded to contribute such further amount over and above the ………. percentage (__%) limit to the extent becoming necessary towards the total equity share in the ……………… (Insert the name of SPV), obligatory on the part of the company pursuant to the terms and conditions contained in the Consortium Agreement dated ……………. executed by the company as per the provisions of the RFP. [Note: In the event, the investing entity is an Affiliate or Parent or Ultimate Parent of the Bidder, the following Board resolution no. 3 shall also be passed by the Bidder] 3. FURTHER RESOLVED THAT the Board hereby acknowledges the Board Resolution(s) passed by the…………………….. [Name of the Affiliate(s)/ Parent / Ultimate Parent] regarding the investment of……….(….%) of the equity share capital requirements of ……………… (Insert the name of SPV), which is to be invested by the …………………………….[Name of the Affiliate(s)/ Parent / Ultimate Parent] for the ……………… (Insert the name of SPV), partly by acquisition of the existing equity shares from ___________[Name of BPC] and partly by subscribing to the new equity shares, as per the terms of the RFP. [Note: The following resolution no. 4 is to be provided by the Bidding Company / Lead Member of the Consortium only] REC Power Development and Consultancy Limited 100RFP for Selection of Bidder as Transmission Service Provider 4. FURTHER RESOLVED THAT MR/MS ……………………………..be and is hereby authorized to take all the steps required to be taken by the Company for submission of the Bid, including in particular, signing of the Bid, making changes thereto and submitting amended Bid, all the documents related to the Bid, certified copy of this Board resolution or letter or undertakings etc, required to be submitted to BPC as part of the Bid or such other documents as may be necessary in this regard. Certified True Copy Company rubber stamp to be affixed [Notes: 1) This certified true copy should be submitted on the letterhead of the Company, signed by the Company Secretary or any Whole Time Director/ Manager (supported by a specific board resolution) of the Bidding Company or the Lead Member of Consortium. 2) The contents of the format may be suitably re-worded indicating the identity of the entity passing the resolution, i.e., the Bidding Company, each Member of the Bidding Consortium. 3) This format may be modified only to the limited extent required to comply with the local regulations and laws applicable to a foreign entity submitting this resolution. For example, reference to Companies Act 1956 / Companies Act 2013 (as the case may be) may be suitably modified to refer to the law applicable to the entity submitting the resolution. However, in such case, the foreign entity shall submit an unqualified opinion issued by the legal counsel of such foreign entity, stating that the Board resolutions are in compliance with the applicable laws of the respective jurisdictions of the issuing company and the authorizations granted therein are true and valid.] REC Power Development and Consultancy Limited 101RFP for Selection of Bidder as Transmission Service Provider Format 2 Format for the Board resolution of Technically / Financially Evaluated Entity / Ultimate Parent Company (in case credentials of such TEE/ FEE has been utilized by the Bidding Company or Bidding Consortium) The Board, after discussion, at the duly convened Meeting on …………………. [Insert date], with the consent of all the Directors present and in compliance of the provisions of the Companies Act, 1956 / 2013, passed the following Resolution: RESOLVED THAT pursuant to the provisions of the Companies Act, 1956 / Companies Act, 2013 (as the case may be) and compliance thereof and as permitted under the Memorandum and Articles of Association of the company, approval of the Board be and is hereby accorded for issuing an Undertaking to the BPC, in the format specified in the RFP issued by the BPC, draft of which is attached hereto and initialed by the Chairman whereby the company undertakes to invest …………….percent (.... %) of the total equity share capital of ……………… (Insert the name of SPV) representing the entire amount proposed to be invested by …………………[insert the name of the Bidder or Member] for the said Project, in case of failure of …………………[Insert the name of the Bidder or Member] to make such investment". FURTHER RESOLVED THAT ............................... ,be and is hereby authorized to take all the steps required to be taken by the Company, including in particular, signing the said Undertaking, submitting the same to the BPC through ………………………………[Insert name of Bidding Company/Lead Member of the Consortium] of all the related documents, certified copy of this Board resolution or letter, undertakings etc, required to be submitted to BPC as part of the Bid or such other documents as may be necessary in this regard. Certified True Copy Company rubber stamp to be affixed Note: 1. This certified true copy should be submitted on the letterhead of the Company, signed by the Company Secretary or any Whole-time Director/Manager (supported by a specific board resolution) of Bidding Company or Lead Member of the Consortium. 2. The contents of the format may be suitably re-worded indicating the identity of the entity passing the resolution. 3. This format may be modified only to the limited extent required to comply with the local regulations and laws applicable to a foreign entity submitting this resolution. For example, reference to Companies Act 1956 / Companies Act 2013 (as the case may be) may be suitably modified to refer to the law applicable to the entity submitting the resolution. However, in such case, the foreign entity shall submit an unqualified opinion issued by the legal counsel of such foreign entity, stating that the Board resolutions are in compliance with the applicable laws of the respective jurisdictions of the issuing company and the authorizations granted therein are true and valid. REC Power Development and Consultancy Limited 102RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 11A – ILLUSTRATION FOR APPLICABLE BOARD RESOLUTION REQUIREMENTS UNDER CLAUSE 2.5.2 Entities (other than Bidder) whose Requirement of credentials (financial Applicable Board Investor in the TSP Undertaking and/or technical) used Resolutions (Annexure 10) by the Bidder for meeting RFP criteria Bidder himself for None a) Format 1 of None 100% equity Annexure 11 - Resolution: 1, 2 and 4 from the Bidder Bidder himself for Affiliate and/or Parent a) Format 1 of Yes, by either 100% equity Company and/or Annexure 11 - Technically / Ultimate Parent Resolution: 1, 2, and Financially Evaluated 4 from the Bidder Entity(ies) Affiliate(s) whose b) Format 2 of credentials have been Annexure 11 by either used, or Ultimate Technically/ Parent. Financially Evaluated Entity(ies) whose Provided, if the Bidder credentials have been himself is the Ultimate used, or Ultimate Parent, then the Parent. undertaking need not be provided. Provided, if the Bidder himself is the Ultimate Parent, then Format 2 need not be provided. Bidder himself + None a) Format 1 of None others (Affiliate Annexure 11 - and/or Parent Resolution: 1,2, 3 Company and/or and4 from the Bidder. Ultimate Parent) in aggregate holding b) Format 1 of 100% equity Annexure 11 - Resolution: 1 from the Affiliate and /or Parent and /or Ultimate Parent investing in the equity Bidder himself + Affiliate and/or Parent a) Format 1 of Yes, by either Parent/ others (Affiliate Company and/or Annexure 11 - Affiliate(s) whose and/or Parent Ultimate Parent Resolution: 1,2, 3 credentials have been Company and/or and 4 from the Bidder. used, or Ultimate Ultimate Parent) in b) Format 1 of Parent aggregate holding Annexure 11 - 100% equity Resolution: 1 from the Affiliate and/or Parent REC Power Development and Consultancy Limited 103RFP for Selection of Bidder as Transmission Service Provider Entities (other than Bidder) whose Requirement of credentials (financial Applicable Board Investor in the TSP Undertaking and/or technical) used Resolutions (Annexure 10) by the Bidder for meeting RFP criteria and/or Ultimate Parent investing in the equity c) Format 2 of Annexure 11 by either Parent / Affiliate(s) whose credentials have been used and /or Ultimate Parent investing in the equity REC Power Development and Consultancy Limited 104RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 12 - FORMAT FOR ILLUSTRATION OF AFFILIATES Indirectly Controls “Bidder” 100% Controls directly “Bidder” >26% >26% Is under Direct common control with Bidder “Bidder” 100% >26% % Is under Indirect Is Controlled directly common control with by “Bidder” “Bidder” 100% Is Controlled indirectly by “Bidder” NOTE: Bidder to provide the illustration, as applicable in their case, duly certified by the Company Secretary and supported by documentary evidence in this regard. REC Power Development and Consultancy Limited 105RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 13 - FORMAT FOR DISCLOSURE [On the letter head of Bidding Company / Each Member in a Bidding Consortium] Date: ………… DISCLOSURE We hereby declare that the following companies with which we/ have direct or indirect relationship are also separately participating in this Bid process as per following details S. No. Name of the Company Relationship 1. 2. 3. In case there is no such company please fill in the column “name of the company” as Nil. Further we confirm that we don’t have any Conflict of Interest with any other company participating in this bid process. Certified as True ………………………………………….. (Signature) Name: .................................................................... Signature & Name of authorized signatory of the Company and Stamp The above disclosure should be signed and certified as true by the authorized signatory of the Bidding Company or of the Member, in case of a Consortium). REC Power Development and Consultancy Limited 106RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 14 - FORMAT OF THE BID BOND FORMAT OF THE UNCONDITIONAL AND IRREVOCABLE BANK GUARANTEE FOR BID BOND (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution.) In consideration of the .................. [Insert name of the Bidder] submitting the Bid inter alia for establishing the Inter-State transmission system for ___________[Name of Project] on build, own, operate and transfer basis, in response to the RFP dated ______ issued by _______[Name of BPC], and the Bid Process Coordinator (hereinafter referred to as BPC) agreeing to consider such Bid of …………………………. [Insert the name of the Bidder] as per the terms of the RFP, the [Insert name and address of the bank issuing the Bid Bond, and address of the Head Office] (hereinafter referred to as "Guarantor Bank") hereby agrees unequivocally, irrevocably and unconditionally to pay to _______[Name of BPC] or its authorized representative at _____[Address of BPC] forthwith on demand in writing from _______[Name of BPC] or any representative authorized by it in this behalf, any amount up to and not exceeding Rupees ________ Only (Rs _____ Crore), on behalf of M/s……………………………….[Insert name of the Bidder]. This guarantee shall be valid and binding on the Guarantor Bank up to and including ……………………… [Date to be inserted on the basis of Clause 2.11 of this RFP] and shall not be terminable by notice or any change in the constitution of the Guarantor Bank or by any other reasons whatsoever and our liability hereunder shall not be impaired or discharged by any extension of time or variations or alternations made, given, or agreed with or without our knowledge or consent, by or between concerned parties. Our liability under this Guarantee is restricted to Rupees ___________ Only (Rs ____ Crore). Our Guarantee shall remain in force until ……………………..[Date to be inserted on the basis of Clause 2.11 of this RFP]. _______[Name of BPC] or its authorized representative shall be entitled to invoke this Guarantee until …………… [Insert Date, which is three sixty five days (365) days after the date in the preceding sentence]. The Guarantor Bank hereby expressly agrees that it shall not require any proof in addition to the written demand from _______[Name of BPC] or its authorized representative, made in any format, raised at the above mentioned address of the Guarantor Bank, in order to make the said payment to _______[Name of BPC] or its authorized representative. The Guarantor Bank shall make payment hereunder on first demand without restriction or conditions and notwithstanding any objection, disputes, or disparities raised by the Bidder or any other person. The Guarantor Bank shall not require _______ [Name of BPC] or its authorized representative to justify the invocation of this BANK GUARANTEE, nor shall the Guarantor Bank have any recourse against _______[Name of BPC] or its authorized representative in respect of any payment made hereunder. This BANK GUARANTEE shall be interpreted in accordance with the laws of India. The Guarantor Bank represents that this BANK GUARANTEE has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Guarantor Bank in the manner provided herein. REC Power Development and Consultancy Limited 107RFP for Selection of Bidder as Transmission Service Provider This BANK GUARANTEE shall not be affected in any manner by reason of merger, amalgamation, restructuring or any other change in the constitution of the Guarantor Bank. This BANK GUARANTEE shall be a primary obligation of the Guarantor Bank and accordingly _______[Name of BPC] or its authorized representative shall not be obliged before enforcing this BANK GUARANTEE to take any action in any court or arbitral proceedings against the Bidder, to make any claim against or any demand on the Bidder or to give any notice to the Bidder to enforce any security held by _______[Name of BPC] or its authorized representative or to exercise, levy or enforce any distress, diligence or other process against the Bidder. Notwithstanding anything contained hereinabove, our liability under this Guarantee is restricted to Rupees _____________ Only (Rs ____ Crore) and it shall remain in force until ………… [Date to be inserted on the basis of Clause 2.11 of RFP], with an additional claim period of three hundred sixty five (365) days thereafter. We are liable to pay the guaranteed amount or any part thereof under this BANK GUARANTEE only if _______[Name of BPC] or its authorized representative serves upon us a written claim or demand. In witness whereof the Bank, through its authorized officer, has set its hand and stamp on this…………….. day of ..................... at……………………………… Witness: 1…………………………………………. Signature: ……………………….. Name and Address Name: ……………..…………….. 2. ……………………………………….. Designation with Stamp: Name and Address Signature ……………………. Attorney as per power of attorney No.…………………………………… For: ……………………………………………………… [Insert Name of the Bank] Banker’s Stamp and Full Address: Dated this………………day of…………. 20…….. Notes: 1. The Stamp Paper should be in the name of the Executing Bank. REC Power Development and Consultancy Limited 108RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 14A- FORMAT OF THE SURETY BOND FOR BID SECURITY FORMAT OF THE SURETY BOND (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution.) In consideration of the ..................[Insert name of the Bidder] submitting the Bid inter alia for establishing the Inter-State transmission system for _____________ [Name of Project] on build, own, operate and transfer basis, in response to the RFP dated issued by _____________ [Name of BPC], and the Bid Process Coordinator (hereinafter referred to as BPC) agreeing to consider such Bid of _____________ [Insert the name of the Bidder] as per the terms of the RFP, the _____________ [Insert name of Surety Insurer issuing the surety bond and address of Head Office] (hereinafter referred to as "Surety Insurer") hereby agrees unequivocally, irrevocably and unconditionally to pay to_____________ [Name of BPC] or its authorized representative at _____________ [Address of BPC] forthwith on demand in writing from _____________.[Name of BPC] or any representative authorized by it in this behalf, any amount up to and not exceeding Rupees _____________ Only (Rs _____________ Crore) (the "Surety Bond"),on behalf of M/s.....................................[Insert name of the Bidder]. This surety bond shall be valid and binding on the Surety Insurer up to and including ........................... [Date to be inserted on the basis of Clause 2.11 of this RFP] and shall not be terminable by notice or any change in the constitution of the Surety Insurer or by any other reasons whatsoever and our liability hereunder shall not be impaired or discharged by any extension of time or variations or alternations made, given, or agreed with or without our knowledge or consent, by or between concerned parties. Our liability under this Surety Bond is restricted to Rupees _____________ Only (Rs _____________ Crore). The Surety Bond shall remain in force until .....................[Date to be inserted on the basis of Clause 2.11 of this RFP]. _____________ [Name of BPC] or its authorized representative shall be entitled to invoke this Surety bond until ............... [Insert Date, which is one hundred eighty (180) days after the date in the preceding sentence]. The Surety Insurer hereby expressly agrees that it shall not require any proof except for the written demand from _____________ Name of BPC] or its authorized representative, made in any format, raised at the above mentioned address of the Surety Insurer, in order to make the said payment to _____________ [Name of BPC] or its authorized representative. The Surety Insurer shall make payment hereunder on first demand without restriction or conditions and notwithstanding any objection, disputes, or disparities raised by the Bidder or any other person. The Surety Insurer shall not require _____________ [Name of BPC] or its authorized representative to justify the invocation of this surety bond, nor shall the Surety Insurer have any recourse against _____________ [Name of BPC] or its authorized representative in respect of any payment made hereunder. This Surety Bond shall be interpreted in accordance with the laws of India. The Surety Insurer represents that this Surety Bond has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Surety Insurer in the manner provided herein. REC Power Development and Consultancy Limited 109RFP for Selection of Bidder as Transmission Service Provider This Surety Bond shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Surety Insurer. This Surety Bond shall be a primary obligation of the Surety Insurer and accordingly _____________ [Name of BPC] or its authorized representative shall not be obliged before enforcing this Surety Bond to take any action in any court or arbitral proceedings against the Bidder, to make any claim against or any demand on the Bidder or to give any notice to the Bidder to enforce any security held by _____________ [Name of BPC] or its authorized representative or to exercise, levy or enforce any distress, diligence or other process against the Bidder. The Surety Insurer declares that it has power to issue this Surety Bond and discharge the obligations contemplated herein, the undersigned is duly authorised and has full power to execute this Surety Bond for and on behalf of the Surety Insurer. Notwithstanding anything contained hereinabove, our liability under this surety bond is restricted to Rupees _____________ Only (Rs _____________ Crore) and it shall remain in force until ............ [Date to be inserted on the basis of Clause 2.11 of RFP], with an additional claim period of one hundred eighty (180) days thereafter. We are liable to pay the guaranteed amount or any part thereof under this Surety Bond only if _____________ [Name of BPC] or its authorized representative serves upon us a written claim or demand. In witness where of: Signature............................................... Name: ................................................... Power of attorney No/ Employee No. as applicable.:…………………… For: ................................................... [Insert Name of the Surety Insurance Company Banker's Seal and Full Address, including mailing address of the Head Office Notes: 1. The Stamp Paper should be in the name of the Executing Insurance Company. REC Power Development and Consultancy Limited 110RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 14B - Format of Payment on Order Instrument to be issued by IREDA/REC/PFC (to be submitted separately for each Project) No. Date …………………………… [Insert name of BPC] Reg: M/s____________________ (insert name of the bidding entity)- Issuance of Payment on Order Instrument for an amount of Rs. ____________________ Dear Sir, 1. At the request of M/s....................... (Insert name of the bidding entity), this Payment on Order Instrument (POI) for an amount of Rs................... (Rupees ....................... (In words)) is being issued by M/s. ....................... (Insert Name of the POI issuing Agency) ('IREDA/REC/PFC'). This Payment on Order Instrument comes into force immediately. 2. In consideration of the ....................... [Insert name of the Bidding Entity] (hereinafter referred to as 'Bidder') submitting the response to RFP issued by [Insert name of BPC] for the project ....................... [Insert name of the project] and ....................... [Insert name of BPC] considering such response to the RFP of M/s........................ [Insert the name of Bidding Entity] as per the terms of the RFP, the ......... ........... [Insert name & address of IREDA/PFC/REC] hereby agrees unequivocally, irrevocably and unconditionally to pay to [Insert name of BPC] at [Insert Name of the Place from the address of the BPC] forthwith without demur on demand in writing from .................. [Insert name of BPC] or any Officer authorized by it in this behalf, any amount up to and not exceeding Rupees [Insert amount not less than the bid bond value indicated in RFP] only, on behalf of M/s. [Insert name of the Bidding Entity]. 3. In consideration of the above facts, IREDA/REC/PFC, having its registered office at ........................ agrees to make payment for the sum of Rs ..................... (in words .....................) to ................. [Insert name of BPC] on the following conditions: a. IREDA/REC/PFC agrees to make payment of the above said amount unconditionally, without demur and without protest within a period of ________ days of receipt of request from ..................... [Insert name of BPC] within the validity period of this letter as specified herein; b. The commitment of IREDA/REC/PFC, under this Payment on Order Instrument will have the same effect as that of the commitment under the Bank Guarantee issued by any Public Sector Bank and shall be enforceable in the same manner as in the case of a Bank Guarantee issued by a Bank and the same shall be irrevocable and shall be honoured irrespective of any agreement or its breach between REC Power Development and Consultancy Limited 111RFP for Selection of Bidder as Transmission Service Provider IREDA/REC/PFC or its constituents notwithstanding any dispute that may be raised by them against ..................... [Insert name of BPC]; c. The liability of IREDA/REC/PFC continues to be valid and binding on IREDA/REC/PFC and shall not be terminated, impaired, and discharged by virtue of change in its constitution and specific liability under this POI shall be binding on its successors or assignors; d. The liability of IREDA/REC/PFC shall continue to be valid and binding on IREDA/REC/PFC and shall not be terminated/impaired/discharged by any extension of time or variation and alteration made, given or agreed with or without knowledge or consent of the parties ([Insert name of BPC] and Bidder), subject however to the maximum extent of amount stated herein and IREDA/REC/PFC is not liable to any interest or costs etc.; e. This Payment on Order Instrument can be invoked either partially or fully, till the date of validity; f. IREDA/REC/PFC agrees that it shall not require any proof in addition to the written demand by [Insert name of BPC] made in any format within the validity period. IREDA/REC/PFC shall not require [Insert name of BPC] to justify the invocation of the POI against the Bidder, to make any claim against or any demand against the Bidder or to give any notice to the Bidder; g. The POI shall be the primary obligation of IREDA/REC/PFC and ................. [Insert name of BPC] shall not be obliged, before enforcing the POI, to take any action in any court or arbitral proceedings against the Bidder; h. The POI shall not be affected in any manner by reason of merger, amalgamation, restructuring or any other changes in constitution of IREDA/REC/PFC; i. Neither the ................. [Insert name of BPC] is required to justify the invocation of this POI nor shall IREDA/REC/PFC have any recourse against the ................. [Insert name of BPC] in respect of the payment made under this POI. 4. Notwithstanding anything contrary contained anywhere in this POI or in any other documents, this POI is and shall remain valid up to [Insert the date of validity of the POI as per Clause 2.11.1 of the RFP], with an additional claim period of three hundred and sixty-five (365) days thereafter and IREDA/REC/PFC shall make payment thereunder only if a written demand or request is raised within the said date and to the maximum extent of Rs................ and IREDA/REC/PFC shall in no case be liable for any interest, costs, charges, and expenses and IREDA's/REC's/PFC's liability in no case will exceed more than the above amount stipulated. 5. In pursuance of the above, IREDA/REC/PFC and [Insert name of BPC] have signed an Umbrella Agreement dated ............... setting out the terms and conditions for issue of letter REC Power Development and Consultancy Limited 112RFP for Selection of Bidder as Transmission Service Provider of undertaking by IREDA/REC/PFC to ................. [Insert name of BPC] and the said terms and conditions shall be read as a part of this POI issued for the project of PP mentioned above. Thanking you, Yours faithfully For and on behalf of M/s..................... (Name of the POI issuing agency) ( ) General Manager Copy to M/s ……………………. As per their request ( ) General Manager REC Power Development and Consultancy Limited 113RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 15 - FORMAT FOR CONTRACT PERFORMANCE GUARANTEE (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign entities submitting Bids are required to follow the applicable law in their country) In consideration of the ………………………… [Insert name of the SPV or Selected Bidder on behalf of SPV or Lead Member in case of the Consortium, with address] agreeing to undertake the obligations under the Transmission Service Agreement dated ………………………… and the other RFP Project Documents and the Nodal Agency and …………_[Name of BPC], agreeing to execute the RFP Project Documents with the Selected Bidder, regarding setting up the Project, the……………………………[Insert name and address of the bank issuing the guarantee and address of the head office] (hereinafter referred to as "Guarantor Bank") hereby agrees unequivocally, irrevocably and unconditionally to pay to the Nodal Agency at………………………… [Insert Place and Address of the Nodal Agency indicated in TSA] forthwith on demand in writing from the Nodal Agency or any Officer authorized by it in this behalf, any amount up to and not exceeding Rupees……………………………Crores (Rs……………….) only [Insert the amount of the bank guarantee] on behalf of M/s……………………… [Insert name of the Selected Bidder / SPV]. This guarantee shall be valid and binding on the Guarantor Bank up to and including ………………..and shall not be terminable by notice or any change in the constitution of the Bank or the term of the Transmission Service Agreement or by any other reasons whatsoever and our liability hereunder shall not be impaired or discharged by any extension of time or variations or alternations made, given, or agreed with or without our knowledge or consent, by or between parties to the respective agreement. Our liability under this Guarantee is restricted to Rupees ……………. Crores (Rs………………………) only. Our Guarantee shall remain in force until…………… [Insert the date of validity of the Guarantee as per Clause 2.12.1 of the RFP]. The Nodal Agency shall be entitled to invoke this Guarantee up to three hundred sixty five (365) days of the last date of the validity of this Guarantee. The Guarantor Bank hereby expressly agrees that it shall not require any proof in addition to the written demand from the Nodal Agency, made in any format, raised at the above mentioned address of the Guarantor Bank, in order to make the said payment to the Nodal Agency. The Guarantor Bank shall make payment hereunder on first demand without restriction or conditions and notwithstanding any objection by ___________[Name of SPV], ………… [Insert name of the Selected Bidder], …………. [Insert name of the TSP] and/or any other person. The Guarantor Bank shall not require the Nodal Agency to justify the invocation of this BANK GUARANTEE, nor shall the Guarantor Bank have any recourse against the Nodal Agency in respect of any payment made hereunder. This BANK GUARANTEE shall be interpreted in accordance with the laws of India. The Guarantor Bank represents that this BANK GUARANTEE has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Guarantor Bank in the manner provided herein. REC Power Development and Consultancy Limited 114RFP for Selection of Bidder as Transmission Service Provider This BANK GUARANTEE shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Guarantor Bank. This BANK GUARANTEE shall be a primary obligation of the Guarantor Bank and accordingly the Nodal Agency shall not be obliged before enforcing this BANK GUARANTEE to take any action in any court or arbitral proceedings against ___________[Name of SPV] or the Selected Bidder, to make any claim against or any demand on ___________[Name of SPV] or the Selected Bidder, as the case may be, or to give any notice to ___________[Name of SPV] or the Selected Bidder, as the case may be, or to enforce any security held by the Nodal Agency or to exercise, levy or enforce any distress, diligence or other process against ………_[Name of SPV] or the Selected Bidder, as the case may be. The Guarantor Bank acknowledges that this BANK GUARANTEE is not personal to the Nodal Agency and may be assigned, in whole or in part, (whether absolutely or by way of security) by Nodal Agency to any entity to whom the Nodal Agency is entitled to assign its rights and obligations under the Transmission Service Agreement. The Guarantor Bank hereby agrees and acknowledges that the Nodal Agency shall have a right to invoke this Bank Guarantee either in part or in full, as it may deem fit. Notwithstanding anything contained hereinabove, our liability under this Guarantee is restricted to Rupees ……………………..Crores (Rs ……………..) only and it shall remain in force until [Date to be inserted on the basis of Article 3.1.2 of TSA], with an additional claim period of three hundred sixty five (365) days thereafter. This BANK GUARANTEE shall be extended from time to time for such period, as may be desired by………………… [Insert name of the Selected Bidder or Lead Member in case of the Consortium or SPV]. We are liable to pay the guaranteed amount or any part thereof under this Bank Guarantee only if the Nodal Agency serves upon us a written claim or demand. In witness where of: Signature……………………………………….. Name: …………………………………………… Power of attorney No.: ………………………... For: …………………………… [Insert Name of the Bank] Banker's Seal and Full Address, including mailing address of the Head Office Notes: 1. The Stamp Paper should be in the name of the Executing Bank. REC Power Development and Consultancy Limited 115RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 15A -FORMAT FOR SURETY INSURANCE CONTRACT (ISB for CPG) (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign entities submitting Bids are required to follow the applicable law of India) In consideration of the .................................. [Insert name of the SPV or Selected Bidder on behalf of SPV or Lead Member in case of the Consortium, with address] (hereinafter referred to as the 'Principal Debtor' for the purposes of this Surety Insurance Contract as provided in Section 126 of the Indian Contract Act, 1872) having been selected to undertake the Transmission Project on the terms and conditions contained in the Transmission Service Agreement dated ..............................I to be executed as per the Model Transmission Service Agreement provided along with the Request for Proposal ('RFP') and other RFP Project Documents, subject to the condition of providing a Performance Bank Guarantee or a Surety Insurance Contract guaranteeing/insuring the due performance of the obligations under the Transmission Service Agreement, to the Central Transmission Utility of India Limited ('CTUIL') [herein after referred to as the Nodal Agency], the [Insert name and address of the Insurance Company issuing the Surety Insurance Contract and address of the head office] (hereinafter referred to as "Surety") hereby agrees unequivocally, irrevocably, absolutely and unconditionally, without demur, to pay to the Nodal Agency at [Insert Place and Address of the Nodal Agency indicated in Transmission Service Agreement, or to the designated Bank Account of the Nodal Agency, namely........] forthwith on demand in writing from the Nodal Agency, or any Officer authorized by it in this behalf, intimated to the Surety at the address mentioned above, any amount as may be decided by the Nodal Agency not exceeding Rupees .................................Crores (Rs...................) only [Insert the amount of the Surety Insurance Contract] The Surety hereby acknowledges, accepts and confirms that the Surety has received from the Principal Debtor, by way of premium the entire consideration for the Surety to execute, in favour of the Nodal Agency, this Surety Insurance Contract, as extended by the Surety from time to time and assuming the obligation to pay to the Nodal Agency the amount in terms hereof, without any requirement for payment of any other consideration to the Surety by the Principal Debtor, or otherwise. This Surety Insurance Contract shall be valid and binding on the Surety, as the principal obligation of the Surety to pay on demand by the Nodal Agency, and shall not be terminable by notice or any change in the constitution of the Surety or the term of the Transmission Service Agreement or by any other reasons whatsoever and the liability hereunder of the Surety shall not be impaired or discharged by any extension of time or variations or alternations made, given, or agreed (with or without the knowledge or consent of the Surety) by or between the Principal Debtor and the Nodal Agency. The liability of the Surety under this Surety Insurance Contract is restricted to Rupees ................ Crores (Rs ................ ) only. The Surety Insurance Contract shall remain in force until [Insert the date of validity of the Surety Insurance Contract]. The Nodal Agency shall be entitled to invoke this Surety Insurance Contract up to three hundred sixty five (365) days after the last date of the validity of this Surety Insurance Contract. REC Power Development and Consultancy Limited 116RFP for Selection of Bidder as Transmission Service Provider The Surety hereby expressly agrees that it shall not require any proof except for the written demand from the Nodal Agency, containing the statement that the contractor has failed to meet its contractual obligations faised at the above mentioned address of the Surety (address of Surety office should be a place in NCR only) and the Surety shall pay the amount without reference to the Principal Debtor. Any such demand made by the Nodal Agency on the Surety shall be conclusive and binding not withstanding any difference between the Nodal Agency and the Principal Debtor or any dispute pending before any Court, Tribunal, Arbitrator or any other authority. The Surety undertakes not to revoke this guarantee during its currency without previous consent of the Nodal Agency and further agrees that the Surety Insurance Contract herein contained shall continue to be enforceable till the Nodal Agency discharges this contract or till the expiry of tenor(including Claim period) whichever is earlier. The Surety shall make payment hereunder within two (02) working days on first demand without restriction or conditions and notwithstanding any objection by the Principal Debtor, namely, ......... [Insert name of SPV], or ......... [Insert name of the Selected Bidder], or ............. [Insert name of the TSP] and/or any other person. The Surety shall not require the Nodal Agency to justify the invocation of this Surety Insurance Contract, nor shall the Surety have any recourse against the Nodal Agency in respect of any payment made hereunder. This SURETY INSURANCE CONTRACT shall be interpreted in accordance with the laws of India. This SURETY INSURANCE CONTRACT is being executed by the Surety in terms of the IRDAI (Surety Insurance Contract) Guidelines, 2022 and the Surety hereby acknowledges, accepts and confirms that this Surety Insurance Contract shall be a Contract of Guarantee as provided under Section 126 of the Indian Contract Act, 1872 and further shall be covered by Section 14(3)(b) of the Insolvency and Bankruptcy Code, 2016 (as amended) shall be enforceable as such. The Surety represents that this Surety Insurance Contract has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Surety in the manner provided herein. This SURETY INSURANCE CONTRACT shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Surety. In order to give effect to this surety Bond, the Nodal Agency shall be entitled to act as if the surety insurer were the principal debtor and any change in the constitution of the contractor and/or the surety insurer, whether by their absorption with any other body or corporation or otherwise, shall not in any way or manner affect the liability or obligation of the surety insurer under this surety Bond. This SURETY INSURANCE CONTRACT shall be a primary obligation of the Surety as a Principal to pay on demand by the Nodal Agency and the Nodal Agency shall not be obliged before enforcing this Surety Insurance Contract to take any action in any court or arbitral proceedings against the Principal Debtor, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert REC Power Development and Consultancy Limited 117RFP for Selection of Bidder as Transmission Service Provider name of the TSP] and/or any other person, as the case may be, to make any claim against or any demand on the Principal Debtor, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or.................................. [Insert name of the TSP] and/or any other person, as the case may be, or to give any notice to Principal Debtor, namely.................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or.................................. [Insert name of the TSP] and/or any other person, as the case may be, or to enforce any security held by the Nodal Agency or to exercise, levy or enforce any distress, diligence or other process against the Principal Debtor, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be. The Surety acknowledges that this Surety Insurance Contract is not personal to the Nodal Agency and may be assigned, in whole or in part, (whether absolutely or by way of security) by Nodal Agency to any entity to whom the Nodal Agency is entitled to assign its rights and obligations under the Transmission Service Agreement Provided that any such assignment shall be in compliance with the relevant provisions of the Insurance Act 1938 The Surety hereby agrees and acknowledges that the Nodal Agency shall have a right to invoke this Surety Insurance Contract either in part or in full, as it may deem fit. In case of invocation of this Surety Insurance Contract in part, besides making payment for the part of Surety Insurance Contract invoked, surety at the request of nodal agency shall amend the value of Surety Insurance Contract to the extent of balance amount. The Surety undertakes not to revoke this Surety Contract during its currency, except with the previous express consent of the Nodal Agency in writing and declares and warrants that it has the power to issue this Surety Contract and the undersigned has full powers to do so on behalf of the Surety In witness where of: Signature............................................... Name: ................................................... Power of attorney No/ Employee No. as applicable. ..................................: For: .................................. [Insert Name of the Surety-Insurance Companyl Banker's Seal and Full Address, including mailing address of the Head Office Notes: 1. The Stamp Paper should be in the name of the Executing Insurance Company. REC Power Development and Consultancy Limited 118RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 15B - FORMAT FOR ISSUANCE OF PAYMENT ON ORDER INSTRUMENT (POI for CPG) Format for Issuance of Payment on Order Instrument Dear Sir, 1. Indian Renewable Energy Development Agency Limited ('IREDA")/PFC/REC has sanctioned a non-fund-based limit loan of Rs. (Rupees............................................. Only) to M/s. .................................. [Insert name of SPV or selected Bidder] under the Loan Agreement executed on ......................... to execute Transmission System Projects. 2. In consideration of the ..................................[Insert name of the SPV or Selected Bidder on behalf of SPV or Lead Member in case of the Consortium, with address] for the purposes of this Payment on Order Instrument ("POI") having been selected to undertake the Transmission Project on the terms and conditions contained in the Transmission Service Agreement dated ..............................I to be executed as per the draft of the Model Transmission Service Agreement provided along with the Request for Proposal (,,RFP") and other RFP Project Documents, subject to the condition of providing a POI guaranteeing the due performance of the obligations under the Transmission Service Agreement to the Nodal Agency/Central Transmission Utility of India Limited (,,CTUIL"), the.................................[Insert name and address of the non-banking financial institutions(IREDA/PFC/REC) issuing the POI and address of the head office] (hereinafter referred to as "Guarantor") hereby agrees unequivocally, irrevocably, absolutely and unconditionally, without demur, to pay to the Nodal Agency at ............................ [Insert Place and Address of the Nodal Agency indicated in Transmission Service Agreement, or to the designated Bank Account of the Nodal Agency, namely ……………….. ] forthwith on demand in writing from the Nodal Agency, or any Officer authorized by it in this behalf, intimated to the Guarantor at the address mentioned above, any amount as may be decided by the Nodal Agency not exceeding Rupees .......................................... Crores (Rs ..................................) only [Insert the amount of Payment on Order Instrument] 3. At the request of ......................... and on behalf of M/s. ............................................., [Insert name of SPV or selected Bidder] this Payment on Order Instrument (POI) for an amount of Rs. ............................. (Rupees .............................) is being issued with IREDA/PFC/REC assuming the obligations to remit such amount to CTUIL from the sanctioned loan. 4. This Payment on Order Instrument comes into force immediately and IREDA/PFC/REC confirms that it has sufficient amount out of the sanctioned loan and shall maintain the required amount to pay under this Payment on Order Instrument, during the validity and claim period of this Payment on Order Instrument. 5. This POI has been issued by IREDA/PFC/REC utilizing the credit limit of M/s......................................................[Insert name of SPV or selected Bidder] REC Power Development and Consultancy Limited 119RFP for Selection of Bidder as Transmission Service Provider IREDA/PFC/REC confirms that its liability to pay under this Payment on Order Instrument shall be primary and independent of whether at the time of invocation of Payment on Order Instrument, the sanctioned funds are available or not and notwithstanding, the status of M/s [Insert name of SPV or selected Bidder] at the relevant time and to whether IREDA/PFC/REC is able to recover the amount advanced by it to the said developer. 6. IREDA/PFC/REC and M/s.[Insert name of SPV or selected Bidder] hereby acknowledges, accepts and confirms that this Payment on Order Instrument shall be a Contract of Guarantee as provided under Section 126 of the Indian Contract Act, 1872 and further shall be covered by Section 14(3)(b) of the Insolvency and Bankruptcy Code, 2016 (as amended) shall be enforceable as such. 7. IREDA/PFC/REC liability under this POI is restricted to Rupees Crores (Rs...........................) only. This POI shall remain in force until............... [Insert the date of validity of the POI]. The Nodal Agency shall be entitled to invoke this POI up to three hundred sixty-five (365) days after the last date of the validity of this POI. This POI shall be extended from time to time for such period, as may be desired by the TSP. 8. The Guarantor hereby expressly agrees that it shall not require any proof except for the written demand from the Nodal Agency, raised at the above mentioned address of the Guarantor (address of Guarantor office should be in NCR only) and the Guarantor shall pay the amount to the Nodal Agency without reference to the TSP. 9. Any such demand made by the Nodal Agency on the Guarantor shall be conclusive and binding not withstanding any difference between the Nodal Agency and the TSP or any dispute pending before any Court, Tribunal, Arbitrator or any other authority. The Guarantor undertakes not to revoke this guarantee during its currency without previous consent of the Nodal Agency and further agrees that the POI herein contained shall continue to be enforceable till the Nodal Agency discharges this contract or till the expiry of tenure or (including Claim period) whichever is earlier. 10. The Guarantor shall make payment hereunder within two (02) working days on first demand without restriction or conditions and notwithstanding any objection or disputes raised by the TSP, namely, .................................. [Insert name of SPV], or [Insert name of the Selected Bidder], or.................................. [Insert name of the TSP] and/or any other person. The Guarantor shall not require the Nodal Agency to justify the invocation of this POI, nor shall the Guarantor have any recourse against the Nodal Agency in respect of any payment made hereunder. 11. This POI shall be interpreted in accordance with the laws of India. 12. The Guarantor represents that this POI Contract has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Guarantor in the manner provided herein. REC Power Development and Consultancy Limited 120RFP for Selection of Bidder as Transmission Service Provider 13. This POI shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Guarantor. 14. This POI Contract shall be a primary obligation of the Guarantor as a Principal to pay on demand by the Nodal Agency and the Nodal Agency shall not be obliged before enforcing this POI Contract to take any action in any court or arbitral proceedings against the TSP, namely, .................................. [Insert name of SPV], or.................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be to make any claim against or any demand on the TSP, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be, or to give any notice to TSP, namely.................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be, or to enforce any security held by the Nodal Agency or to exercise, levy or enforce any distress, diligence or other process against the TSP, namely, .................. [Insert name of SPV], or.[Insert name of the Selected Bidder], or ............. [Insert name of the TSP] and/or any other person, as the case may be. 15. The Guarantor acknowledges that this POI Contract is not personal to the Nodal Agency and may be assigned, in whole or in part, (whether absolutely or by way of security) by Nodal Agency to any entity to whom the Nodal Agency is entitled to assign its rights and obligations under the Transmission Service Agreement. 16. The Guarantor hereby agrees and acknowledges that the Nodal Agency shall have a right to invoke this POI Contract either in part or in full, as it may deem fit. In case of invocation of this POI Contract in part, besides making payment for the part of POI Contract invoked, Guarantor at the request of Nodal Agency shall amend the value of POI Contract to the extent of balance amount. IN WITNESS WHERE OF the non- banking financial institutions through its authorized officer, has set its hand and stamp on this....... day of........at......... Signature .............................................. Name: .................................. Power of attorney No.: .................................. For: .................................. [Insert Name of the non- banking financial institutions Company] Seal and Full Address, including mailing address of the Head Office REC Power Development and Consultancy Limited 121RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 16 – FORMAT OF CHECKLIST FOR TECHNICAL BID SUBMISSION REQUIREMENTS [This format needs to be duly filled in, signed by the authorized signatory of the Bidder (Bidding Company / Lead Member in case of a Bidding Consortium) and submitted along with the Bidder’s Technical Bid] Response Technical Bid Submission Requirements (Yes / No) 1. Format for the Covering Letter on the letterhead of Bidding Company or Lead Member of the Consortium, as applicable; 2. Format for Letter of Consent from each Consortium Member, including Lead Member, on their respective letterheads; 3. Format for evidence of authorized signatory’s authority; 4. Board resolution from the Bidding Company / Lead Member of the Consortium in favour of the person executing the Power of Attorney as per Annexure 3; 5. Power of Attorney from each Consortium Member in favour of Lead Member to be provided by each of the other Members of the Consortium as per Annexure 4; 6. Board Resolution from each Member of the Consortium, other than the Lead Member, in favour of their respective authorized representatives for executing the POA, Consortium Agreement and signing of the requisite formats; 7. Format for Bidder’s composition and ownership structure, along with status of equity holding (owning ten percent or more of the total paid up equity) not earlier than thirty (30) days prior to the Bid Deadline as per Annexure 5; 8. Consortium Agreement duly signed as per Annexure 6, along with Appendix-1, indicating the responsibilities and obligations of each Member of the Consortium; 9. Format for Qualification Requirement: a. Calculation sheets, detailing computation of Net-worth considered for meeting Qualifying Requirements, duly signed and stamped by the Statutory Auditor of the Bidding Company / each Member in case of a Bidding Consortium / FEE in cases where credentials of FEE is taken; b. Calculation sheets, detailing computation of capital expenditure of projects and revenue received in construction projects considered for meeting Qualification Requirements, duly signed and stamped by the Statutory Auditor of the Bidding Company / Lead Member in case of Bidding Consortium / TEE in cases where credentials of TEE is taken; REC Power Development and Consultancy Limited 122RFP for Selection of Bidder as Transmission Service Provider Response Technical Bid Submission Requirements (Yes / No) c. Last financial year unconsolidated / consolidated audited annual accounts / statements, as the case may be, of the Financially Evaluated Entity / Technical Evaluated Entity d. Unconsolidated audited annual accounts of both the TEE and the Bidding Company/Lead member, as applicable, from the financial years in which financial closure was achieved till the financial year in which the said project was completed / commissioned. 10. Copy of the Memorandum and Articles of Association and certificate of incorporation or other organizational document (as applicable), including their amendments, certified by the Company Secretary of Bidding Company or each Member in case of a Consortium including Lead Member. 11. Attachment of Annexure 7(D), detailing projects completed / commissioned and for which commercial operation has commenced including Executive Summary for each project. 12. For each project listed in the attachment above, certified true copy of the certificates of final acceptance and / or certificates of good operating performance duly issued by owners or clients for the project, duly signed by authorized signatory in support of technical capability as defined in Clause 2.1.2 of RFP. 13. Authority letter in favour of BPC from the Bidder/every Member of the Consortium authorizing the BPC to seek reference from their respective bankers & others. 14. Authorization from Parent / Affiliate of Bidding Company / Member of Bidding Consortium whose technical / financial capability has been used by the Bidding Company / Member of Bidding Consortium. 15. Initialing of all pages of Technical Bid by the Authorized Signatory in whose favour the POA (Annexure 3) has been executed. 16. Format for Illustration of Affiliates at the most seven (7) days prior to the Bid Deadline, duly certified by Company Secretary and supported by documentary evidence. 17. Certified copy of the Register of Members / Demat Account Statement, Share Certificate, Annual Return filed with ROC etc. submitted as documentary evidence along with Annexure 12. 18. Format for Disclosure by Bidding Company / each Member of the Consortium. 19. Format for Affidavit by the Bidding Company / each Member of the Consortium REC Power Development and Consultancy Limited 123RFP for Selection of Bidder as Transmission Service Provider Response Technical Bid Submission Requirements (Yes / No) 20. Format for Authorization submitted in Non-Judicial stamp paper duly notarized. 21. Bidders Undertaking and details of Equity Investment 22. Proof of Payment of RFP Fees 23. Bid Bond/Surety Bond/Payment on Order Instrument 24. Board Resolution as per Annexure 11 (If required) [Note: The checklist is not exhaustive. Bidders are required to submit all the information/documents as per requirement of RFP] For and on behalf of Bidder M/s. ………………………………………………. ………………………………………………….. (Signature of authorized signatory) REC Power Development and Consultancy Limited 124RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 17 – LIST OF BANKS All Scheduled Commercial Banks as per Second Schedule of RBI Act-1934 and any amendments thereof. REC Power Development and Consultancy Limited 125RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 18 - GRID MAP OF THE PROJECT Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I) REC Power Development and Consultancy Limited 126RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 19 - FORMAT FOR CLARIFICATIONS / AMENDMENTS ON THE RFP / RFP PROJECT DOCUMENTS Rationale for Clause No. Suggested the Name of the Clarification S. No. and Existing text for the Clarification Document required provision amendment or Amendment Signature ……………………………… Name…………………………………... For Bidder’s Rubber Stamp and Full Address. (Note: This format shall be used for submission of requests for clarifications/ amendments on the draft RFP Project Documents as per the provisions of Clause 2.3.1) REC Power Development and Consultancy Limited 127RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 20 - LIST FOR RFP PROJECT DOCUMENTS ENCLOSURE 1: TRANSMISSION SERVICE AGREEMENT (Provided separately) ENCLOSURE 2: SHARE PURCHASE AGREEMENT (Provided Separately) REC Power Development and Consultancy Limited 128RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 21 - FORMAT FOR FINANCIAL BID [To be uploaded online] Quoted Transmission Charges ……….. Notes 1. The Bidders are required to ensure compliance with the provisions of Clause 2.5.3 of this RFP. 2. Quotes to be in Rupees Millions and shall be up to two (2) decimal points. 3. The contents of this format shall be clearly typed. 4. The Financial Bid shall be digitally signed by the authorized signatory in whose name power of attorney as per Clause 2.5.2 is issued. 5. Ensure only one value for annual Transmission Charges is quoted. The same charge shall be payable every year to TSP for the term of TSA. REC Power Development and Consultancy Limited 129RFP for Selection of Bidder as Transmission Service Provider ANNEXURE 22 – FORMAT FOR AFFIDAVIT [On non-judicial stamp paper. Foreign companies submitting bids are required to follow the applicable law in their country] AFFIDAVIT We [including any of our Affiliate and Consortium Member & any of its Affiliate], hereby declare that as on Bid Deadline: a. the Bidder & any of its Affiliate including any Consortium Member & any of its Affiliate, their directors or key personnel have not been barred or included in the blacklist by any government agency or authority in India, the government of the jurisdiction of the Bidder or Members where they are incorporated or the jurisdiction of their principal place of business, any international financial institution such as the World Bank Group, Asian Development Bank, African Development Bank, Inter-American Development Bank, Asian Infrastructure Investment Bank etc. or the United Nations or any of its agencies; or b. the Bidder & any of its Affiliate including any Consortium Member & any of its Affiliate or their directors have not been convicted of any offence in India or abroad. We further declare that following investigations are pending / no investigation is pending [strike off whichever is not applicable] against us [including any of our Consortium Member or Affiliate or Parent or Ultimate Parent or Affiliate] or CEO or any of our directors/ manager/key managerial personnel of the Applicant /Consortium Member or their Affiliates. We further undertake to inform the BPC of any such matter as mentioned above on its occurrence after the date of this affidavit till the Effective Date. We undertake that, in case, any information provided in relation to this affidavit is found incorrect at any time hereafter, our BID / Letter of Intent / contract (if entered) would stand rejected / recalled / terminated, as the case may be. ……………………………………. Signature and Name of the authorized signatory of the Company Bidding Company / Lead Member of the Bidding Consortium ………………………….. (Signature of Notary Public) Place: ………………………… Date: ………………………… Note: In case any investigation is pending against the Applicant, including any Consortium Member or Affiliate, or CEO or any of the directors/ manager/key managerial personnel of the REC Power Development and Consultancy Limited 130RFP for Selection of Bidder as Transmission Service Provider Applicant /Consortium /Member or their Affiliates, full details of such investigation including the name of the investigating agency, the charge/offence for which the investigation has been launched, name and designation of persons against whom the investigation has been launched and other relevant information should be disclosed under this affidavit. REC Power Development and Consultancy Limited 131RFP for Selection of Bidder as Transmission Service Provider ANNEXURE A Technical Details with respect to electronic bidding Registration Methodology In order to submit online bids in the e-bidding process for selection of Transmission Service Provider, interested Bidders are required to register themselves with the e-procurement website of MSTC Limited namely www.mstcecommerce.com/eprochome/tsp/index.jsp. To register with the website, the Bidder is required to fill up the online form available under the link Register as Vendor in the above website and fill up the same and click on Submit. During this process, the bidder shall create his user id and password and keep note of the same. The bidder shall ensure that the secrecy of his user id and password is maintained at all time and he/she shall alone be responsible for any misuse of the user id and password. The bidder may check the details entered by it before final submission. On successful submission of the online registration Form, the bidder shall receive a confirmation mail in the registered email address advising the bidder to submit the following documents. i. Self-attested Income Tax PAN Card. In case of a registered Company or Firm, the Firm's PAN card and in case of a proprietorship firm, proprietor’s personal PAN card is required. In case of partnership firm, PAN of the firm and that of the authorized partner are to be submitted. ii. Copy of the confirmation email Letter received from MSTC after successful completion of on-line registration. iii. A non-refundable registration fee of Rs 10,000/- plus applicable GST to be paid online. Please provide details of payment made like UTR No, remitting bank name, date of payment and amount in the covering letter. The bidder shall have to submit all the above documents to MSTC Limited for verification and activation of their login ids. The bidders should send scanned copies of the above documents to the designated email id only which is given below. tsp@mstcindia.co.in It may be noted that bidders need not visit any of the offices of MSTC Limited for submission of the documents. Contact persons of MSTC Limited: Mr. Setu Dutt Sharma, 7878055855 Once the complete set of documents and requisite registration fee are received from a bidder, MSTC shall activate the bidder’s login after verification / scrutiny of the documents. MSTC Limited reserves the right to call for additional documents from the bidder if needed and the bidder shall be obliged to submit the same. On completion of the above stated registration process, a bidder shall be able to login to MSTC’s website. REC Power Development and Consultancy Limited 132RFP for Selection of Bidder as Transmission Service Provider ANNEXURE B Draft Pre-Award Integrity Pact GENERAL This pre-bid contract Agreement (herein after called the Integrity Pact) is made on …………….. day of the month of …………. 20………, between, on one hand, ……………………………………. [Insert name of BPC] through Shri ……………………….. [Insert Name & designation of representative of BPC] (hereinafter called the "Bid Process Coordinator/ BPC", which expression shall mean and include, unless the context otherwise requires, his successors in the office and assigns) of the First Part and M/s ………………………… represented by Shri ……………………………………….. [Insert Name & Designation of Authorized Signatory of the Bidder/ Lead Member of Consortium] (hereinafter called the "Bidder" which expression shall mean and include, unless the context otherwise requires, his successors and permitted assigns) of the Second Part. WHEREAS the BPC is conducting the bidding process for selection of bidder as Transmission Service Provider (TSP) for “Transmission system for proposed Green Hydrogen / Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” who will be responsible to set up the transmission project on build, own, operate and transfer (BOOT) basis and to provide Transmission Service. WHEREAS the Bidder is a Private Company/Public Company/Government Undertaking/ Partnership, constituted in accordance with the relevant law in the matter and the BPC is a Public Sector Undertaking (PSU) performing its function on behalf of the Ministry of Power, Government of India. NOW, THEREFORE, To avoid all forms of corruption by following a system that is fair, transparent and free from any influence/prejudiced dealings during the complete bidding process with a view to:- Enabling the BPC to select the bidder as TSP in conformity with the defined procedures by avoiding the high cost and the distortionary impact of corruption on public procurement, and Enabling Bidder to abstain from bribing or indulging in any corrupt practice in order to emerge as selected bidder by providing assurance to them that their competitors will also abstain from bribing and other practices and the BPC will commit to prevent corruption, in any form, by its officials by following transparent procedures. The parties hereto hereby agree to enter into this Integrity Pact and agree as follows: REC Power Development and Consultancy Limited 133RFP for Selection of Bidder as Transmission Service Provider Commitments of BPC 1.1 The BPC undertakes that no official of the BPC, connected directly or indirectly with the bidding process, will demand, take a promise for or accept, directly or through intermediaries, any bribe, consideration, gift, reward, favour or any material or immaterial benefit or any other advantage from the BIDDER, either for themselves or for any person, organization or third party related to the bidding process in exchange for an advantage in the bidding process, bid evaluation, contracting or implementation process related to the contract. 1.2 The BPC will, during the bidding stage, treat all bidders alike, and will provide to all bidders the same information and will not provide any such information to any particular bidder which could afford an advantage to that particular bidder in comparison to the other bidders. 1.3 All the officials of the BPC will report the appropriate Government office any attempted or completed breaches of the above commitments as well as any substantial suspicion of such a breach. 2. In case of any such preceding misconduct on the part of such official(s) is reported by the Bidder to the BPC with the full and verifiable facts and the same is prima facie found to be correct by the BPC, necessary disciplinary proceedings, or any other action as deemed fit, including criminal proceedings may be initiated by the BPC and such a person shall be debarred from further dealings related to the bidding process. In such a case while an enquiry is being conducted by the BPC the proceedings under the bidding process would not be stalled. Commitments of Bidder 3. The Bidder commits itself to take all measures necessary to prevent corrupt practices, unfair means and illegal activities during any stage of its bid or during any pre award stage in order to emerge as Selected Bidder or in furtherance to secure it and in particular commits itself to the following: - 3.1 The Bidder will not offer, directly or through intermediaries, any bribe, gift, consideration, reward, favour, any material or immaterial benefit or other advantage, commission, fees, brokerage or inducement to any official of the BPC, connected directly or indirectly with the bidding process, or to any person, organization or third party related to the bidding process in exchange for any advantage in the bidding, evaluation, contracting and implementation of the bidding process. 3.2 The Bidder further undertakes that it has not given, offered or promised to give, REC Power Development and Consultancy Limited 134RFP for Selection of Bidder as Transmission Service Provider directly or indirectly any bribe, gift, consideration, reward, favour, any material or immaterial benefit or other advantage, commission, fees, brokerage or inducement to any official of the BPC or otherwise in bidding process or for bearing to do or having done any act in relation to bidding process or any other contract with the Government for showing or forbearing to show favour or disfavour to any person in relation to the bidding process or any other contract with the Government. 3.3 The Bidder shall disclose the name and address of agents and representatives and Indian Bidder shall disclose their foreign principals or associates. 3.4 The Bidder shall disclose the payments to be made by them to agents/brokers or any other intermediary, in connection with this bid. 3.5 The Bidder further confirms and declares to the BPC that the Bidder has not engaged any individual or firm or company whether Indian or foreign to intercede, facilitate or in any way to recommend to the BPC or any of its functionaries, whether officially or unofficially for selection of Bidder as TSP, nor has any amount been paid, promised or intended to be paid to any such individual, firm or company in respect of any such intercession, facilitation or recommendation. 3.6 The Bidder, either while presenting the bid or during pre-award negotiations or before signing the Share Purchase Agreement, shall disclose any payments he has made, is committed to or intends to make to officials of the BPC or their family members, agents, brokers or any other intermediaries in connection with the bidding process and the details of services agreed upon for such payments. 3.7 The Bidder will not collude with other parties interested in the bidding process to impair the transparency, fairness and progress of the bidding process. 3.8 The Bidder will not accept any advantage in exchange for any corrupt practice, unfair means and illegal activities. 3.9 The Bidder shall not use improperly, for purpose of competition or personal gain, or pass on to others, any information provided by the BPC as part of the business relationship, regarding plans, technical proposal and business details, including information contained in any electronic data carrier. The Bidder also undertakes to exercise due and adequate care lest any such information is divulged. 3.10 The Bidder commits to refrain from giving any complaint directly or through any other manner without supporting it with full and verifiable facts. 3.11 The Bidder shall not instigate or cause to instigate any third person to commit any of the actions mentioned above. REC Power Development and Consultancy Limited 135RFP for Selection of Bidder as Transmission Service Provider 3.12 The Bidder shall not lend to or borrow any money from or enter into any monetary dealings or transactions, directly or indirectly, with any employee of the BPC. 4. Previous Transgression 4.1 The Bidder declares that no previous transgression occurred in the last three years immediately before signing of this Integrity Pact, with any other company in any country in respect of any corrupt practices envisaged hereunder or with any Public Sector Enterprise in India or any Government Department in India that could justify Bidder’s exclusion from the bidding process. 4.2 The Bidder agrees that if it makes incorrect statement on this subject, Bidder can be disqualified from the tender process or the contract, if already awarded, can be terminated for such reason. 5. Bid Bond (Security Deposit) 5.1 Along with the technical bid, the Bidder shall submit Bid Bond for an amount of Rs. …………………………. (as per the amount specified in Request for Proposal (RFP) Document) issued by …………………………………… [Insert Name of the Banks from the list provided in RFP Document] as Earnest Money/Security Deposit, with the BPC. 5.2 The Earnest Money/Security Deposit shall be valid & retained by the BPC for such period as specified in the RFP Document. 5.3 No interest shall be payable by the BPC to the Bidder on Earnest Money/Security Deposit for the period of its currency. 6. Sanctions for Violations 6.1 Any breach of the aforesaid provisions by the Bidder or any one employed by it or acting on its behalf (whether with or without the knowledge of the Bidder) shall entitle the BPC to take all or anyone of the following actions, wherever required: - (i) To immediately call off the pre-award negotiations without assigning any reason or giving any compensation to the Bidder. However, the proceedings with the other Bidder (s) would continue. (ii) The Bid Bond (in pre-award stage) shall stand forfeited either fully or partially, as decided by the BPC and the BPC shall not be required to assign any reason therefore. REC Power Development and Consultancy Limited 136RFP for Selection of Bidder as Transmission Service Provider (iii) To immediately cancel the award, if already awarded, without giving any compensation to the Bidder. (iv) To cancel all or any other contracts with the Bidder. The Bidder shall be liable to pay compensation for any loss or damage to the BPC resulting from such cancellation/rescission. (v) To debar the Bidder from participation in any tender or RFP issued by any BPC for an indefinite period. (vi) To recover all sums paid in violation of this Pact by Bidder to any middleman or agent or broker with a view to securing the award. 6.2 The BPC will be entitled to take all or any of the actions mentioned at para 6.1 (i) to (vi) of this Pact also on the Commission by the Bidder or anyone employed by it or acting on its behalf (whether with or without the knowledge of the Bidder), of an offence as defined in Chapter IX of the Indian Penal code, 1860 or Prevention of Corruption Act, 1988 or any other statute enacted for prevention of corruption. 6.3 The decision of the BPC to the effect that a breach of the provisions of this Pact has been committed by the Bidder shall be final and conclusive on the Bidder. However, the Bidder can approach the Independent Monitor(s) appointed for the purposes of this Pact. 7. Independent Monitors 7.1 The BPC has appointed Independent Monitors (hereinafter referred to as Monitors) for this Pact in consultation with the Central Vigilance Commission (Names and Addresses of the Monitors to be given). 7.2 The task of the Monitors shall be to review independently and objectively, whether and to what extent the parties comply with the obligations under this Pact. 7.3 The Monitors shall not be subject to instructions by the representatives of the parties and perform their functions neutrally and independently. 7.4 Both the parties accept that the Monitors have the right to access all the documents relating to the project/procurement, including minutes of meetings. 7.5 As soon as the Monitor notices, or has reason to believe, a violation of this Pact, he will so inform the Authority designated by the BPC. 7.6 The Bidder accepts that the Monitors has the right to access without restriction to all REC Power Development and Consultancy Limited 137RFP for Selection of Bidder as Transmission Service Provider Project documentation of the BPC including that provided by the Bidder. The Monitor shall be under contractual obligation to treat the information and documents of the Bidder /Subcontractors(s) with confidentially. [As all the bid documents are with BPC only] 7.7 The BPC will provide to the Monitors sufficient information about all meetings among the parties related to the Project provided such meetings could have an impact on the contractual relations between the parties. The parties will offer to the monitor the option to participate in such meetings. 7.8 The Monitor will submit a written report to the designated Authority of the BPC/Secretary in the Department within 8 to 10 weeks from the date of reference or intimation to him by the BPC / Bidder and, should the occasion arise, submit proposals for correcting problematic situations. 8. Facilitation of Investigation In case of any allegation of violation of any provisions of this Pact or payment of commission, the BPC or its agencies shall be entitled to examine all the documents including the Books of Accounts of the Bidder and the Bidder shall provide necessary information and documents in English and shall extend all possible help for the purpose of such examination. 9. Law and Place of Jurisdiction This Pact is subject to Indian Law. The place of performance and jurisdiction is the seat of the BPC. 10. Other Legal Actions The actions stipulated in this Integrity Pact are without prejudice to any other legal action that may follow in accordance with the provisions of the any extent law in force relating to any civil or criminal proceedings. 11. Validity 11.1 The validity of this Integrity Pact shall be from date of its signing and upto 6 months from the date of transfer of project specific SPV i.e. signing of Share Purchase Agreement with BPC. In case Bidder is unsuccessful, this Integrity Pact shall expire after 15 days from the date of transfer of project specific SPV to successful bidder. 11.2 Should one or several provisions of this Pact turn out to be invalid, the remainder of this Pact shall remain valid. In this case, the parties will strive to come to an agreement to their original intentions. REC Power Development and Consultancy Limited 138RFP for Selection of Bidder as Transmission Service Provider 12. The Parties hereby sign this Integrity Pact at on Bid Process Coordinator (BPC) BIDDER Name of the Officer Designation Name of Whole time Director/Authorized Name of the BPC with address Signatory Name of the Bidder with address Witness: Witness: 1. 1. 2. 2. REC Power Development and Consultancy Limited 139RFP for Selection of Bidder as Transmission Service Provider ANNEXURE C Technical Specifications of Transmission System SPECIFIC TECHNICAL REQUIREMENTS FOR TRANSMISSION LINE The design, routing and construction of transmission lines shall be in accordance with Chapter V, Part A of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Other CEA Regulations/ guidelines as amended up to date and Ministry of Power (MoP) guidelines, as applicable, shall also be followed. A.1.0 Selection of tower type shall be made as per CEA Regulations, however, in case lattice type towers are used, the following shall also be applicable: A.2.0 Steel section of grade E 250 and/or grade E 350 as per IS 2062, only are permitted for use in towers, extensions, gantry structures and stub setting templates. For towers in snowbound areas, steel sections shall conform to Grade-C of IS-2062. A.3.0 Towers shall be designed as per IS-802:2015, however the drag coefficient of the tower shall be as follows: - Solidity Ratio Drag Coefficient Up to 0.05 3.6 0.1 3.4 0.2 2.9 0.3 2.5 0.4 2.2 0.5 and above 2.0 A.4.0 Transmission Service Provider (TSP) shall adopt any additional loading/ design criteria for ensuring reliability of the line, if so desired and /or deemed necessary. A.5.0 Transmission line shall be designed considering wind zones as specified in wind map given in National Building Code 2016, Vol.1. The developer shall also make his own assessment of local wind conditions and frequent occurrences of High Intensity Winds (HIW) due to thunderstorms, dust storms, downburst etc. along the line route and wherever required, higher wind zone than that given in wind map shall be considered for tower design for ensuring reliability of line. Further, for transmission line sections passing within a distance of 50 km from the boundary of two wind zones, higher of the two wind zones shall be considered for design of towers located in such sections. A.6.0 Selection of reliability level for design of tower shall be as per CEA Regulation (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. A.7.0 REC Power Development and Consultancy Limited 140RFP for Selection of Bidder as Transmission Service Provider a) In case of construction of transmission line of Voltage level of 400 kV and above, under crossing of the existing transmission line shall not be allowed. In the case where it is inevitable to under-cross the existing transmission line then TSP shall seek prior approval from Chief Electrical Inspector, CEA with detailed study ensuring that all statutory electrical clearances and Electric Field limit of 10 kV/m at 1 m and 1.8 m from ground level is not violated. b) For power line crossing of 400 kV or above voltage level, large angle and dead end towers (i.e. D/DD/QD) shall be used on either side of power line crossing. c) For power line crossing of 132 kV and 220 kV (or 230 kV) voltage level, angle towers (B/C/D/DB/DC/DD/ QB/QC/QD) shall be used on either side of power line crossing depending upon the merit of the prevailing site condition and line deviation requirement. d) For power line crossing of 66 kV and below voltage level, suspension/tension towers shall be provided on either side of power line crossing depending upon the merit of the prevailing site condition and line deviation requirement. e) For crossing of railway tracks, national highways and state highways, the rules/ regulations of appropriate authorities shall be followed. A.8.0 The relevant conductor configuration shall be as follows: - A. For 765 kV lines under the scheme: i) Pendurthi (Vizag) – Srikakulam 765 kV D/c line ii) Khammam-II – Warangal New 765 kV D/c line iii) Khammam-II – Pendurthi (Vizag) 765 kV D/c line Type of conductor: ACSR / AAAC / AL59 Basic Parameters: ACSR Transmission Equivalent Equivalent Sub- Conductor line AAAC minimum size of conductor specified conductor based AL59 conductor Spacing on 53.5% based on 59% conductivity of conductivity of Al Alloy AL Alloy* 765 kV D/C Zebra: Stranding Stranding Stranding (Hexa Bundle) 54/3.18 mm-Al + details: details: Transmission 7/3.18 mm-Steel, 61/3.19 mm, 61/3.08 mm, Lines 428.9 mm2, Aluminium area, 487.5 mm2 454 mm2 457 mm Aluminium alloy Aluminium alloy area area REC Power Development and Consultancy Limited 141RFP for Selection of Bidder as Transmission Service Provider ACSR Transmission Equivalent Equivalent Sub- Conductor line AAAC minimum size of conductor specified conductor based AL59 conductor Spacing on 53.5% based on 59% conductivity of conductivity of Al Alloy AL Alloy* 28.62 mm 28.71 mm 27.72 mm diameter diameter diameter Maximum DC Maximum DC Maximum DC Resistance at Resistance at Resistance at 20°C (Ω/km): 20°C (Ω/km): 20°C (Ω/km): 0.0677 0.06815 0.0653 Minimum UTS: Minimum UTS: Minimum UTS: 131.44 kN 135.6 kN 108 kN B. For 400 kV lines under the scheme: i) Khammam-II – Khammam (existing) 400 kV (quad) D/c line ii) LILO of Kalpakka – Maradam 400 kV (quad) D/c line at Pendurthi Type of conductor: ACSR / AAAC / AL59 Basic Parameters: Transmission Equivalent AAAC Equivalent Sub- ACSR line conductor based on minimum size of conductor Conductor 53% conductivity of AL59 conductor Spacing specified Al Alloy based on 59% conductivity of AL Alloy* 400 kV D/C Moose: Stranding Stranding details: Stranding details: (Quad Bundle) 54/3.53mm-Al + 61/3.55mm 61/3.31mm Transmission 7/3.53 mm- Steel, 31.95mm 29.79 mm Lines 31.77 mm diameter diameter; diameter; 528.5 mm2, 604 mm2 525 mm2 457 mm Aluminium area, Aluminium alloy Aluminium alloy area area REC Power Development and Consultancy Limited 142RFP for Selection of Bidder as Transmission Service Provider Maximum DC Maximum DC Maximum DC Resistance at 20°C Resistance at 20°C Resistance at 20°C (Ω/km): 0.0549 (Ω/km): 0.05506 (Ω/km): 0.0566 Minimum UTS: Minimum UTS: Minimum UTS: 159.60 kN 159.80 kN 124.70 kN Note: 1. *To select any size above the minimum, the sizes mentioned in the Indian standard IS-398 (part-6) shall be followed. 2. The transmission lines shall have to be designed for a maximum operating conductor temperature of 85 OC. A.9.0 The required phase to phase spacing and horizontal spacing for 765 kV and 400 kV line(s) shall be governed by the tower design as well as minimum live metal clearances for 765 kV and 400 kV voltage level under different insulator swing angles. However, the phase to phase spacing for 765 kV line shall not be less than 15 m and for 400 kV line shall not be less than 8 m. A.10.0 All electrical clearances including minimum live metal clearance, ground clearance and minimum mid span separation between earth wire and conductor as given below shall be considered: I. Minimum live metal clearances for 765 kV line: (i) Under stationary conditions From tower body: For 765 kV D/C: 6.1 m For 765 kV S/C: 5.6 m (ii) Under swing conditions Wind Pressure Condition Minimum Electrical Clearance a) Swing angle (25º) 4.4 m b) Swing angle (55º) 1.3 m (iii) Minimum ground clearance for 765 kV line: 18 m (iv) Minimum mid span separation between earth-wire and conductor for 765 kV line: 9.0 m II. Minimum live metal clearances for 400 kV line: (i) Under stationary conditions From tower body: 3.05 m (ii) Under swing conditions Wind pressure Condition Minimum electrical clearance REC Power Development and Consultancy Limited 143RFP for Selection of Bidder as Transmission Service Provider a) Swing angle (22º) 3.05 m b) Swing angle (44º) 1.86 m (iii) Minimum ground clearance for 400 kV line: 8.84 m (iv) Minimum mid span separation between earth-wire and conductor for 400 kV line: 9.0 m A.11.0 Shielding angle shall not exceed 10 deg for 765 kV D/C and 20 deg for 400 kV D/C Line transmission line. A.12.0 The Fault current for design of line shall be 50 kA for 1 sec for 765 kV and 63 kA for 1 sec for 400 kV. A.13.0 In case of 400 kV and above voltage class lines, at least one out of two earth wires shall be OPGW and second earth wire, if not OPGW, shall be either of Galvanized Stranded Steel (GSS) or Aluminum Alloy Conductor Steel Reinforced (AACSR) conductor type or any other suitable conductor type depending upon span length and other technical consideration. A.14.0 Each tower shall be earthed such that tower footing impedance does not exceed 10 ohms. Pipe type or Counterpoise type earthing shall be provided in accordance with relevant IS. Additional earthing shall be provided on every 7 to 8 km distance for direct earthing of both shield wires. If site condition demands, multiple earthing or use of earthing enhancement compound shall be used. A.15.0 Pile type foundation shall be used for towers located in river or creek bed or on bank of river having scourable strata or in areas where river flow or change in river course is anticipated, based on detailed soil investigation and previous years’ maximum flood discharge of the river, maximum velocity of water, highest flood level, scour depth and anticipated change in course of river based on river morphology data of at least past 20 years to ensure availability and reliability of the transmission line. A.16.0 Transmission line route shall be finalized, in consultation with appropriate authorities so as to avoid the habitant zones of endangered species and other protected species. Bird diverters, wherever required, shall be provided on the transmission line. In order to optimize the route, use of GATISHAKTI platform shall also be made. A.17.0 Wherever, transmission lines are passing through cyclone prone areas i.e., areas up to 60 km from coast following shall also be applicable: a) Terrain category-I, with terrain roughness factor (K2) of 1.08 shall be considered for tower design for exposed open terrain with few or no obstruction, which also includes open sea coasts, open stretch of water, desert and flat treeless plains. b) Importance factor for cyclonic region (K4) of 1.3 shall be considered for tower design. c) The number of consecutive spans between the section points/ angle point shall not exceed 10 spans or 3 km instead of conventional practice of 15 spans or 5 km, in REC Power Development and Consultancy Limited 144RFP for Selection of Bidder as Transmission Service Provider order to reduce the failure of such towers in coastal areas due to cascading effect. The section shall be terminated with tension tower/ angle tower and angle of deviation should be based on the site requirement. A.18.0 Wherever, transmission lines are passing through cyclone prone areas (i.e. areas up to 60 km from coast)/ creek regions/ aggressive soil areas following shall also be applicable: a) The fabricated tower parts and stubs shall have a minimum overall zinc coating of 900 g/m2 of surface area except for plates and sections below 5 mm which shall have a minimum overall zinc coating of 610 g/m2 of surface area. The average zinc coating for all sections and plates 5 mm and above shall be maintained as 127 microns and that for plates and sections below 5 mm shall be maintained as 87 microns. b) Ready mix concrete of M30 Grade shall be used to avoid use of locally available saline water. However, design mix concrete of M30 Grade conforming to IS 456 with potable water can be used at locations where transportation of ready-mix concrete is not feasible. Minimum cement content in any case shall not be less than 330 kg/m3. c) The surface of the reinforced steel shall be treated with epoxy-based coating to enhance corrosion performance of foundation. Use of epoxy coated reinforcement in foundation shall be as per IS 13620. In addition, two (2) coats of bituminous painting of minimum 1.6 kg/m2 per coat shall be applied on all exposed faces of foundation (i.e. pedestal and base slab). d) Double coat 20 mm thick cement plaster shall be provided on all exposed concrete surface as well as up to 300 mm below the ground level to provide protection to concrete surface from environmental and saline effect. e) Before coping of chimney top portion, three coats of anti-corrosive paint of minimum 30-35 microns dry film thickness each shall be applied on the stub in the 50 mm coping portion as well as up to 350 mm above CL portion. A.19.0 The raised chimney foundation is to be provided in areas prone to flooding/water stagnation like paddy field /agricultural field and undulated areas to avoid direct contact of water with steel part of tower. The top of the chimney of foundation should be at least above High Flood Level (HFL) or the historical water stagnation/ logging level (based on locally available data) or above High Tide Level or 500 mm above Natural Ground level (whichever is higher). A.20.0 Routing of transmission line through protected areas shall be avoided to the extent possible. In case, it is not possible to avoid protected areas, the towers of the transmission line up to 400 kV level, which are installed in protected areas shall be designed for Multicircuit (4 circuits) configuration of same voltage level considering reliability level of at least two (2). The top two circuits of these multi-circuit towers shall be used for stringing of the transmission line under present scope and the bottom two circuits shall be made available for stringing of any future transmission line of any transmission service REC Power Development and Consultancy Limited 145RFP for Selection of Bidder as Transmission Service Provider providers/ State transmission utilities/Central transmission utilities passing through the same protected area. Further, the configuration and coordinates of such transmission towers shall be submitted to CEA, CTU and BPC by the TSP. A.21.0 The TSP shall abide by the Guidelines of CEA w.r.t. shifting of transmission lines for NHAI projects and other projects. A.22.0 Safety precautions in regards to gas/oil pipelines in vicinity of Transmission lines shall be taken in coordination with gas/ petroleum authorities. A.23.0 The stringing of the transmission line in the forest area shall be carried out through drones. A.24.0 The tower shall be designed considering the porcelain Insulators with creepage factor of 31 mm/ kV irrespective of type of insulator used. A.25.0 RoW width and Span in different terrain shall be as per Schedule VII of CEA (Technical Standards for Construction of Electrical plants and Electric Lines) Regulations 2022, as amended from time to time. REC Power Development and Consultancy Limited 146RFP for Selection of Bidder as Transmission Service Provider SPECIFIC TECHNICAL REQUIREMENTS FOR SUBSTATION The proposed Pendurthi (Vizag) S/s shall be conventional Gas Insulated Switchgear (GIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations, 2022, as amended from time to time. The proposed Khammam-II S/s shall be conventional Air Insulated Switchgear (AIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Extension of proposed Srikakulam S/s shall be conventional Gas Insulated Switchgear (GIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Extension of proposed Khammam S/s and Warangal New S/s shall be conventional Air Insulated Switchgear (AIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Other CEA Regulations/guidelines as amended up to date and MoP guidelines, as applicable, shall also be followed. B.1.0 Salient features of Substation Equipment and Facilities The design and specification of substation equipment are to be governed by the following factors: B.1.1 Insulation Coordination The system design parameters for substations/switchyards shall be as given below: Sl. Description of parameters 765/400kV 765/400 kV No. Khammam-II S/s (AIS) Pendurthi (Vizag) S/s (GIS) 765 kV 400 kV 765 kV 400 kV System System System System 1. System Operating Voltage 765 kV 400 kV 765 kV 400 kV 2. Maximum voltage of the 800 kV 420 kV 800 kV 420 kV system (rms) 3. Rated Frequency 50 Hz 50 Hz 50 Hz 50 Hz 4. No. of Phases 3 3 3 3 5. Rated Insulation Levels REC Power Development and Consultancy Limited 147RFP for Selection of Bidder as Transmission Service Provider Sl. Description of parameters 765/400kV 765/400 kV No. Khammam-II S/s (AIS) Pendurthi (Vizag) S/s (GIS) 765 kV 400 kV 765 kV 400 kV System System System System i) Lightning Impulse Withstand Voltage for (1.2/50 micro sec.) 2100 kVp 1425 kVp 2100 1425 kVp - for Equipment other kVp than Transformer and 2100 kVp 1550 kVp 1550 Reactor 2100 kVp - for Insulator String kVp ii) Switching Impulse withstand 1550 kVp 1050 kVp 1425 kVp 1050 kVp voltage (250/2500 micro sec.) (for GIS) dry and wet 1550 kVp (for AIS) iii) One minute power frequency 830 kV 630 kV 960 kV 650 kV dry withstand voltage (rms) (for GIS) (for GIS) 830 kV 630 kV (for AIS) (for AIS) 6. Corona Extinction Voltage 508 kV 320 kV 508 kV 320 kV 7. Max. radio interference 2500 1000 2500 1000 voltage for frequency micro-volts micro-volts micro-volt micro-volt between 0.5 MHz and 2 MHz at 508 kV rms at 266 kV at 508 kV at 266 kV rms rms rms 8. Minimum creepage distance 24800 mm 13020 mm 24800 mm 13020 mm for insulator string/ longrod (31 mm/kV) (31 mm/kV) (31 insulators/ outdoor bushings (31mm/kV) mm/kV) 9. Minimum creepage distance 20000 mm 10500 mm 24800 mm 13020 mm for switchyard equipment (25 mm/kV) (25 mm/kV) (31 mm/kV) (31 mm/kV) 10. Max. Fault Current 50 kA 63 kA 50 kA 63 kA 11. Duration of Fault 1 sec 1 sec 1 sec 1 sec Sl. Description of parameters 765 kV 765 kV 400 kV No. Srikakulam S/s Warangal Khammam (GIS) New S/s S/s (AIS) (AIS) 765 kV 765 kV 400 kV System System System 1. System Operating Voltage 765 kV 765 kV 400 kV REC Power Development and Consultancy Limited 148RFP for Selection of Bidder as Transmission Service Provider Sl. Description of parameters 765 kV 765 kV 400 kV No. Srikakulam S/s Warangal Khammam (GIS) New S/s S/s (AIS) (AIS) 765 kV 765 kV 400 kV System System System 2. Maximum voltage of the system 800 kV 800 kV 420 kV (rms) 3. Rated Frequency 50 Hz 50 Hz 50 Hz 4. No. of Phases 3 3 3 5. Rated Insulation Levels i) Lightning Impulse withstand voltage for (1.2/50 micro sec.) - for Equipment other than 2100 kVp 2100 kVp 1425 kVp Transformer and Reactor - for Insulator String 2100 kVp 2100 kVp 1550 kVp ii) Switching Impulse withstand 1425 kVp 1550 kVp 1050 kVp voltage (250/2500 micro sec.) dry (for GIS) and wet 1550 kVp (for AIS) iii) One minute power frequency dry 960 kV 830 kV 630 kV withstand voltage (rms) (for GIS) 830 kV (for AIS) 6. Corona Extinction Voltage 508 kV 508 kV 320 kV 7. Max. radio interference voltage for 2500 2500 1000 frequency between 0.5 MHz and 2 micro-volt at micro-volts micro-volts MHz 508 kV rms at 508 kV rms at 266 kV rms 8. Minimum creepage distance for 24800 mm 24800 mm 13020 mm insulator string/ longrod (31 mm/kV) (31 mm/kV) (31 mm/kV) insulators/ outdoor bushings 9. Minimum creepage distance for 24800 mm 20000 mm 10500 mm switchyard equipment (31 mm/kV) (25 mm/kV) (25 mm/kV) 10. Max. Fault Current 50 kA 50 kA 63 kA 11. Duration of Fault 1 sec 1 sec 1 sec B.1.2 Switching Scheme The switching schemes, as mentioned below, shall be adopted at various voltage levels of substation/switchyard: REC Power Development and Consultancy Limited 149RFP for Selection of Bidder as Transmission Service Provider Substation 765 kV side 400 kV side 765/400 kV Pendurthi (Vizag) S/s (GIS) One and Half breaker One and Half breaker 765/400 kV Khammam-II S/s (AIS) One and Half breaker One and Half breaker 765 kV Srikakulam S/s (GIS) One and Half breaker ------ 765 kV Warangal New S/s (AIS) One and Half breaker ------ 400 kV Khammam S/s (AIS) ------ One and Half breaker Notes: - i) For one and half breaker switching scheme, any double circuit line consisting of two numbers of feeders and originating from the same transmission or generating switchyard shall not be terminated in one diameter. ii) Two transformers of same HV rating shall not be connected in the same diameter and similarly two bus reactors of same HV rating shall also not be connected in the same diameter. iii) A diameter in one and half breaker scheme is a set of 3 circuit breakers with associated isolators, earth switches, current transformers etc. for controlling 2 (two) numbers of feeders. iv) In case of GIS substation where the bus scheme is One and Half breaker scheme, the diameters shall be complete with feeder/line side isolator and GIS duct of the future bay shall be brought outside the GIS hall/building with extension/interface module suitably. v) Connection arrangement of Switchable Line reactors shall be such that it can be used as Line reactor as well as Bus reactor with suitable NGR bypass arrangement. vi) Space for 765 kV and 400 kV future line bays shall be kept considering provision of switchable line reactors. vii) Provision for Bus sectionalizer: Space for One (1) set of bus sectionalizer for 400 kV shall comprise Two (2) Nos. of bus sectionalizer bays with associated Circuit Breakers, Isolators and Current Transformers for both buses. Space for One (1) set of bus sectionalizer for 220 kV shall comprise Two (2) Nos. of bus sectionalizer bays with associated Circuit Breakers, Isolators and Current Transformers for both buses. viii) TSP shall plan connectivity of line and transformer feeders to bus bar in such a way that all power can be evacuated successfully without crossing the thermal limit at any point of bus-bar. REC Power Development and Consultancy Limited 150RFP for Selection of Bidder as Transmission Service Provider ix) For AIS type substation, TSP shall keep space provisions for future elements such that interconnection arrangement to the corresponding future bays can be done with overhead AIS type connection without any cable/ GIS duct. x) 765/400 kV Pendurthi (Vizag) S/s: 765 kV bay configure ations (one and half breaker scheme) shall be as follows: Configuration Numbers ICT- Tie- Line 4 (four) Bus Reactor-Tie-Future Line with Switchable Line Reactor* 1 (one) 400 kV bay configurations (one and half breaker scheme) shall be as follows: Configuration Numbers ICT (400 kV side of 765/400 kV ICT)- Tie- Line 4 (four) STATCOM-Tie-Future Line with Switchable Line Reactor* 1 (one) Note (*): GIS modules for Line Bay and Switchable Line Reactor shall be provided by TSP under present scope. xi) 765/400 kV Khammam-II S/s: 400 kV Bus Sectionalization shall be with the following feeder distribution. 400 kV Bus Section-1 400 kV Bus Section-2 (future) a) 3 Nos. of Present 765/400 kV ICT a) 3 Nos. of future765/400 kV ICT b) 2 Nos. of Present 400 kV Lines b) 5 Nos. of future 400/220 kV ICT c) 5 Nos. of future 400/220 kV ICT c) 6 Nos. of Future 400 kV Lines (with d) 4 Nos. of Future 400 kV Lines (with provision for Switchable line provision for Switchable line reactor) reactor) TSP shall implement 400 kV bays keeping the space provision for providing 400 kV Bus Sectionalizer in future meeting the requirements of feeder distribution as mentioned above. xii) 765 kV Srikakulam S/s: Pendurthi (Vizag) - Srikakulam 765 kV D/c line shall be terminated in 2 nos. of existing diameters. GIS modules for these Line Bays and Switchable Line Reactor at Srikakulam is being implemented under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid”. Switchable Line Reactor, Line termination equipment (such as SF6 to Air Bushings with associated GIS duct, LA, CVT and Wave trap), Protection panels, PLCC etc. as required shall REC Power Development and Consultancy Limited 151RFP for Selection of Bidder as Transmission Service Provider be provided under present scope. xiii) 765 kV Warangal New S/s: - Khammam-II – Warangal New 765 kV D/c line shall be terminated in 2 nos. of new diameters (Line bays 704 and 707) for which Main and Tie bays shall be constructed under present scope. Refer attached SLD- 5427PS102-WGL-E-SYD-SYS-0001-SL, Rev 3 at B.5. xiv) 400 kV Khammam S/s: One circuit of Khammam-II - Khammam 400 kV D/c line shall be terminated in existing diameter for which Main Bay shall be provided under present scope. Other circuit shall be terminated in new diameter for which Main bay and Tie bay shall be provided under present scope. xv) In one and half breaker scheme, both main bay and tie bay shall be completed for controlling a feeder. Further, all associated interconnection work shall also be in the present scope of TSP. B.2.0 Substation Equipment and Facilities (Voltage level as applicable): The switchgear shall be designed and specified to withstand operating conditions and duty requirements. All equipment shall be designed considering the following capacity. 765/400 kV Pendurthi (Vizag) 765/400 kV Khammam-II Sl. Description of S/s (GIS) S/s (AIS) No Bay 765 kV 400 kV 765 kV 400 kV 1. Bus Bar 5000 A 5000 A 4000 A 4000 A 2. Line bay 3150 A 3150 A 3150 A 3150 A 3. ICT bay 3150 A 3150 A 3150 A 3150 A 4. Reactor bay 3150 A N/A 3150 A N/A 5. STATCOM Bay N/A 3150 A N/A N/A 765 kV Srikakulam 400 kV 765 kV Warangal Sl. Description of S/s Khammam S/s New S/s (AIS) No Bay (GIS) (AIS) 765 kV 765 kV 400 kV 1. Bus Bar As per existing As per existing As per existing 2. Line bay 3150 A 3150 A 3150 A 3. Reactor bay 3150 A N/A N/A B.2.1 (765/3)/(400/3)/33 kV, Single Phase Autotransformer 500 MVA, (765/3)/ (400/3)/ 33 kV, 1-phase autotransformer (including arrangement for 3-phase bank formation of 1500 MVA) shall conform to CEA’s “Standard Specifications and Technical Parameters for Transformers and Reactors (66 kV and above Voltage Class)” as amended up to date available on CEA’s website. Spare 1-phase Transformer unit shall be placed and connected in such a way that the spare REC Power Development and Consultancy Limited 152RFP for Selection of Bidder as Transmission Service Provider unit can be utilized to replace any unit of any of the transformer banks (including for future transformer banks) without physically moving it. B.2.2 (765/3) kV, Single Phase Shunt Reactor 110 MVAr, 765/3 kV, 1-Phase Reactor (including arrangement for 3-phase bank formation of 330 MVAr) shall conform to CEA’s “Standard Specifications and Technical Parameters for Transformers and Reactors (66 kV and above voltage class)” as amended up to date available on CEA website. Spare 1-phase Shunt Reactor unit shall be placed and connected in such a way that the spare unit can be utilized for all the bus and switchable line reactor banks (including for future reactor banks) without its physical movement. Neutral Grounding Reactor and Surge Arrester for 765 kV Switchable Line Reactors (as applicable): The neutral of the switchable line reactors (wherever provided) shall be grounded through adequately rated Neutral Grounding Reactors (NGR) to facilitate single phase auto- reclosure, provided that the NGR shall be provided with suitable bypass arrangement so that the switchable line reactor can be used as bus reactor as and when required. The neutral of bus reactor shall be solidly grounded. NGR shall be oil filled or dry type air core for outdoor application. NGR shall conform to CEA’s “Standard specifications and technical parameters of transformers and reactors (66 kV and above Voltage Class)”, as amended up to date. Technical parameters of NGR shall be as specified in Annexure-A of above-mentioned document. The surge arresters (rated voltage of arrester in co-ordination with ohmic value of NGR shall be decided by the TSP) shall be provided and physically located between the neutral of shunt reactor (brought out at 145 kV class bushing) and neutral grounding reactor. The surge arresters shall be of Station Medium (SM) class duty gapless Metal Oxide (ZnO) type conforming in general to IEC-60099-4. Arresters shall be hermetically sealed units, of self-supporting construction, suitable for mounting on structures. The Ohmic value of NGR for Line Reactors shall be as follows: Sl. No. Line Name Substation Name NGR value (Ohm) 1. Pendurthi (Vizag) – Srikakulam Srikakulam S/s 500 765 kV D/c line (about 200 km) with 330 MVAr SLR (convertible) at Srikakulam end on both circuits 2. Khammam-II – Pendurthi (Vizag) Pendurthi (Vizag) 400 765 kV D/c line (about 350 km) S/s REC Power Development and Consultancy Limited 153RFP for Selection of Bidder as Transmission Service Provider Sl. No. Line Name Substation Name NGR value (Ohm) with 330 MVAr SLR (convertible) Khammam-II S/s 400 at both ends on both circuit B.2.3 765 kV and 400 kV GIS Substation equipment GIS (Gas Insulated Switchgear) shall be Indoor type in accordance to IEC: 62271-203. The switchgear shall be designed and specified to withstand operating conditions and duty requirements. All the switchgear such as Circuit Breaker, isolator, earth switch including CT, PT etc. shall be GIS type. The Surge Arrestor and Voltage Transformer shall be either GIS or outdoor AIS type. The GIS assembly shall consist of separate modular compartments e.g. Circuit Breaker compartment, Bus bar compartment filled with SF6 Gas and separated by gas tight partitions so as to minimize risk to human life, allow ease of maintenance and limit the effects of gas leaks failures and internal arcs etc. These compartments shall be designed to minimize the risk of damage to adjacent sections and protection of personnel in the event of a failure occurring within the compartments. Rupture diaphragms with suitable deflectors shall be provided to prevent uncontrolled bursting pressures developing within the enclosures under worst operating conditions, thus providing controlled pressure relief in the affected compartment. The arrangement of gas sections or compartments shall be such as to facilitate future extension of any make without any drilling, cutting or welding on the existing equipment. To add equipment, it shall not be necessary to move or dislocate the existing switchgear bays. The layout of Gas Insulated Bus Ducts shall be properly planned to optimize the length of bus ducts and for easy accessibility for maintenance. The length of busbars, bus ducts, isolator sections shall be optimized considering effects of fast transient voltage due to isolator operations. The bus bar modules including auxiliary bus modules (wherever applicable) shall be provided with suitable End Piece (Interface) module on both sides with the test link facility for future extension as per provisions of future requirements. The end piece module shall be designed in such a way so that future GIS modules may be tested without extending test voltage to existing bus and vice-versa by removing the test link. TSP shall make available the complete details for the design of interface module such as cross section, enclosure material, enclosure dimensions (inner and outer), Flange diameter (inner and outer), conductor cross-section and connection arrangement, bolt spacing and dimension, rated gas pressure, Gasket detail etc. Further, adequate space for GIS busbar interface module shall be taken into account for future scope. Each section shall have plug-in or easily removable connection pieces to allow for easy replacement of any component with the minimum disturbance to the remainder of the equipment. Inspection windows (View Ports) shall be provided for Disconnector REC Power Development and Consultancy Limited 154RFP for Selection of Bidder as Transmission Service Provider Switches and both type of earth switches i.e. Maintenance and fast operating. Local Control Cabinets (LCC) shall be provided as per requirement. The alarm and annunciation of GIS equipment shall be wired to the SCADA System. The material and thickness of the enclosures shall be such as to withstand an internal flashover without burns through for a period of 300 ms at rated short time withstand current. The material shall be such that it has no effect of environment as well as from the by-products of SF6 breakdown under arcing conditions. This shall be validated with Type Test. Service continuity requirement for GIS: The GIS equipment with the given bus switching arrangement shall be divided into different gas compartments. During the work such as a fault repair or major maintenance, requiring the dismantling of a gas compartment for which more than one compartments may need to be de-gassed. TSP shall meet following Service continuity conditions (to the extent possible) with ensuring equipment and operating personnel’s safety: For One and half breaker bus switching scheme, during a fault in Circuit Breaker compartment, no bus bar and feeder is permitted out of service during maintenance and repair/replacement. During a fault in a GIS compartment other than the Circuit Breaker compartment, maximum of one bus bar and/or one feeder is permitted out of service during maintenance and repair/replacement. UHF sensors in GIS for PD (Partial Discharge) detection: The adequate number of Ultra High Frequency (UHF) sensors shall be provided in the offered GIS along with suitable portable type Partial Discharge (PD) measuring instrument for detection of Partial discharge (of 5 pC and above as per IEC 60270). The number and location of these sensors shall be based on laboratory tests on the typical design of GIS as per recommendations of CIGRE Document No. 654 (Application Guide for sensitivity verification for UHF Partial discharge detection system for GIS). B.2.3.1 Circuit Breakers (GIS) GIS Circuit breakers shall in general be of C2-M2 class and comply to IEC-62271-100. The rated break time shall not exceed 40 ms (milli second) for 765 kV and 400 kV. Circuit breakers shall be suitable for single phase and three phase auto reclosing. Each breaker would have two sets of trip circuits which would be connected to separate DC supplies for greater reliability. The Circuit breakers controlling 765 kV lines shall be provided either with pre-insertion closing resistor of about 450 ohms with 9 ms insertion time or with Controlled Switching Device (CSD). The Circuit breakers controlling 400 kV lines wherever required shall be provided with pre-insertion closing resistor of about 400 ohms with 8 ms insertion time or Controlled Switching Device (CSD) for lines longer than 200 km. The short line fault capacity shall be the same as the rated capacity and this is REC Power Development and Consultancy Limited 155RFP for Selection of Bidder as Transmission Service Provider proposed to be achieved without use of opening resistors. Controlled switching device shall be provided in the Circuit Breaker of the switchable line reactor bay and in Main and Tie bay circuit breakers of line with non-switchable line reactors, Bus reactors and Transformers for 400 kV and above voltage class. B.2.3.2 Isolators (GIS) The isolators shall comply to IEC 62271-102 in general. Earth switches shall be provided at various locations to facilitate maintenance. Main blades and earth blades shall be interlocked and interlock shall be fail safe type. All isolators and earth switches shall be motor operated type. The isolator shall be of extended mechanical endurance class-M2 and suitable for Bus Transfer Current Switching duty as per IEC standards. High speed earthing switches shall be provided for grounding purposes at overhead line terminations and cable terminations and shall have fault making capability as specified. Earth switch for line isolator shall be of earthing switch class E1 and shall be suitable for induced current switching duty as defined for Class-B as per relevant standard. B.2.3.3 Current Transformers (GIS) Current Transformers shall comply with IEC 61869 in general. All ratios shall be obtained by secondary taps only. Generally, Current Transformers (CT) shall have five cores (four for protection and one for metering) whereas; CT in Tie bays shall have six cores (four for protections and two for metering) suitably distributed on both sides of CB (for 400 kV and above voltage class).The burden and knee point voltage shall be in accordance with the requirements of the system including possible feeds for telemetry. The accuracy class for protection core shall be PX and for the metering core it shall be 0.2S. The rated burden of cores shall be closer to the maximum burden requirement of metering and protection system (not more than 20 VA for metering core) for better sensitivity and accuracy. The instrument security factor shall be less than 5 for CTs up to 400 kV voltage class and less than 10 for CTs of 765 kV voltage class. B.2.3.4 Voltage Transformer (GIS) The voltage transformers shall conform to IEC-61869. Voltage transformers shall be of electromagnetic type with SF6 gas insulation. The earth end of the high voltage winding and the ends of the secondary winding shall be brought out in the terminal box. The voltage transformers shall be located as a separate bay module and will be connected phase to ground and shall be used for protection, metering and synchronization. The voltage transformers shall be of inductive type, nonresistant and shall be contained in their own-SF6 compartment, separated from other parts of installation. The voltage transformer shall be effectively shielded against high frequency electromagnetic transients. The voltage transformer shall have three secondary windings out of which two shall be used for protection and one for metering. The voltage transformer should be thermally and dielectrically safe when the secondary terminals are loaded with the REC Power Development and Consultancy Limited 156RFP for Selection of Bidder as Transmission Service Provider guaranteed thermal burdens. The accuracy class for protection cores shall be 3P. The accuracy of 0.2 on metering core should be maintained throughout the entire burden range on all the three windings without any adjustments during operation. The rated burden of cores shall be closer to the maximum burden requirement of metering and protection system (not more than 50 VA for metering core) for better sensitivity and accuracy. B.2.3.5 Surge Arresters (GIS) (if applicable) 624 kV Station High (SH) duty and 336 kV Station High (SH) duty gapless type Surge arresters with thermal energy (Wth) of minimum 13 kJ/ kV and 12 kJ/ kV respectively shall be provided for 800 kV and 420 kV system respectively conforming to IEC 60099- 4 in general. Other characteristics of Surge arrester shall be chosen in accordance with system requirements. Surge arresters shall be provided at line entrances, near transformers and reactors so as to achieve proper insulation coordination. A leakage current monitor with surge counter shall be provided with each surge arrester. B.2.3.6 SF6 to Air Bushing Outdoor bushings, for the connection of conventional external conductors to the SF6 metal enclosed switchgear, shall be provided. Bushings shall generally be in accordance with the requirements of IEC-60137. The creepage distance over the external surface of outdoor bushings shall not be less than 31 mm/ kV. SF6 to air Bushing shall be of Polymer/ composite type and shall be robust and designed for adequate cantilever strength to meet the requirement of seismic conditions. The electrical and mechanical characteristics of bushings shall be in accordance with IEC-60137. Polymer/composite insulator shall be seamless sheath of silicon rubber compound. The housing and weather sheds should have silicon content of minimum 30% by weight. It should protect the bushing against environmental influences, external pollution and humidity. The hollow silicon composite insulators shall comply with the requirements of IEC 61462 and the relevant parts of IEC-62217. B.2.4 765 kV and 400 kV AIS Substation equipment (as applicable) B.2.4.1 Circuit Breakers (AIS) The circuit breakers and accessories shall conform to IEC: 62271-100, IEC: 62271-1 and shall be of SF6 Type. The circuit breakers shall be of class C2-M2 (as per IEC) with regard to restrike probability during capacitive current breaking and mechanical endurance. The rated break time shall not exceed 40 ms for 765 kV and 400 kV circuit breakers. The 765 kV and 400 kV circuit breakers shall be provided with single phase and three phase auto reclosing. Each breaker would have two sets of trip circuits, which would be connected to separate DC supplies for greater reliability. The circuit breakers controlling 765 kV lines shall be provided either with pre-insertion closing resistor of about 450 ohm maximum with 9 ms insertion time or with Controlled Switching Device. The Circuit breakers controlling 400 kV lines shall be provided with pre insertion closing resistor of about 400 ohm with 8 ms insertion time or Controlled Switching Device (CSD) REC Power Development and Consultancy Limited 157RFP for Selection of Bidder as Transmission Service Provider for lines longer than 200 km length. The short line fault capacity shall be same as the rated capacity and this is proposed to be achieve without use of opening resistors. The controlled switching device shall be provided in circuit breakers of switchable line reactor bay and in Main and Tie bay circuit breakers of line with non-switchable line reactors, Bus Reactors and Transformers of voltage class 400 kV and above. B.2.4.2 Isolators (AIS) The Isolators shall comply with IEC 62271-102 in general. 765 kV Isolator design shall be double break or vertical break or knee-type. 400 kV Isolators shall be double break type. All Isolators and earth switches shall be motor operated. Earth switches shall be provided at various locations to facilitate maintenance. Isolator rated for 400 kV shall be of extended mechanical endurance class – M2 as per IEC-62271-102. Main blades and earth blades shall be interlocked and interlock shall be fail safe type. The 765 kV and 400 kV earth switches for line isolator shall be suitable for induced current switching duty as defined for Class-B. B.2.4.3 Current Transformers (AIS) Current Transformers shall comply with IEC 61869 in general. All ratios shall be obtained by secondary taps only. Generally, Current Transformers (CT) for 765 kV and 400 kV shall have six cores (four for protection and two for metering). The burden and knee point voltage shall be in accordance with the requirements of the system including possible feeds for telemetry. The accuracy class for the protection core shall be PX and for the metering core it shall be 0.2S. The rated burden of cores shall be closer to the maximum burden requirement of the metering and protection system (not more than 20 VA for metering core) for better sensitivity and accuracy. The instrument security factor shall be less than five (5) for CTs up to 400 kV and less than ten (10) for CTs of 765 kV voltage class. B.2.4.4 Capacitive Voltage Transformers (AIS) Capacitive Voltage Transformers shall comply with IEC 61869 in general. These shall have three secondaries out of which two shall be used for protection and one for metering. The Accuracy class for protection cores shall be 3P and for metering core shall be 0.2. The Capacitive Voltage Transformers on lines shall be suitable for Carrier Coupling. The Capacitance of CVT for 400 kV shall be of 4400/8800 pF depending on PLCC requirements whereas the Capacitance of CVT for 765 kV shall be 8800 pF. The rated burden of cores shall be closer to the maximum burden requirement of metering and protection system (not more than 50 VA for metering core) for better sensitivity and accuracy. B.2.4.5 Surge Arresters (AIS) 624 kV and 336 kV Station High (SH) duty gapless type Surge Arresters with thermal energy (Wth) of minimum 13 kJ/kV and 12 kJ/kV conforming to IEC 60099-4 in general shall be provided for 800 kV and 420 kV systems respectively. Other characteristics of Surge Arrester shall be chosen in accordance with system requirements. Surge Arresters REC Power Development and Consultancy Limited 158RFP for Selection of Bidder as Transmission Service Provider shall be provided at line entrances, near transformers and reactors so as to achieve proper insulation coordination. Surge Arresters shall be provided with porcelain/ polymer housing fitted with pressure relief devices. A leakage current monitor with surge counter shall be provided with each surge arrester. B.2.5 Protection Relaying and Control System The protective relaying system proposed to be provided for transmission lines, auto- transformers, reactors and bus bars to minimize the damage to the equipment in the events of faults and abnormal conditions, is dealt in this section. All main protective relays shall be numerical type with IEC 61850 communication interface and should have interoperability during integration of numerical relays to communicate over IEC61850 protocol with RTU/SAS/IEDs of different OEMs. All numerical relays shall have built in disturbance recording feature. The protection circuits and relays of the transformer and reactor shall be electrically and physically segregated into two groups each being independent and capable of providing uninterrupted protection even in the event of one of the protection groups failing, to obtain redundancy, and to take protection systems out for maintenance while the equipment remains in service. a) Transmission Lines Protection 765 kV and 400 kV lines shall have Main-I numerical three zone distance protection scheme with carrier aided inter-tripping feature. 765 kV and 400 kV lines shall also have Main-II numerical distance protection scheme like Main-I but from different make that of Main-I. The Main-I and Main-II protection relays of same make may be provided only if they are of different hardware and manufacturing platform or different principle of operation. However, Line Current Differential Relay (with back up distance protection feature) as Main–I and Main-II shall be considered at both ends for short lines (line length below 30 km) having Fiber Optic Communication Link. Differential relay at remote end shall be provided by the TSP. The associated power and control cabling and integration with SAS at remote end shall be provided by respective bay owners. In case of loop in loop out of transmission lines, the existing protection scheme shall be studied and suitable up-gradation (if required) shall be carried out. Further, all 765 kV and 400 kV lines shall be provided with single and three phase auto- reclosing facility to allow reclosing of circuit breakers in case of transient faults. These lines shall also be provided with distance to fault locators to identify the location of fault on transmission lines. All 765 kV and 400 kV lines shall also be provided with two stage over voltage protection. The over voltage protection and distance to fault locator may be provided as in-built feature of Main-I and Main-II protection relays. Auto reclose as built-in function of Bay Control Unit (BCU) is also acceptable. REC Power Development and Consultancy Limited 159RFP for Selection of Bidder as Transmission Service Provider The Main-I and Main-II protection relays shall be fed from separate DC sources and shall be mounted in separate panels. For 765 kV and 400 kV transmission lines, directional Inverse Definite Minimum Time (IDMT) earth fault relay should be provided as standalone unit or in-built feature of Main- I and Main -II feature. b) Auto Transformer Protection These shall have the following protections: i) Numerical Differential Protection ii) Numerical Restricted Earth Fault Protection iii) Numerical Back-up Over-Current and Earth Fault Protection on High Voltage (HV) and Intermediate Voltage (IV) side iv) Numerical Over Fluxing Protection on HV and IV side v) Numerical Overload Alarm Further, Numerical Back-up Over-current and earth fault protection on HV and IV side of auto-transformer shall not be combined with other protective functions in the main relays and shall be independent relays. Besides these, power transformers shall also be provided with Buchholz relay, Magnetic Oil Gauge (MOG) with low oil level alarm, protection against high oil and winding temperature and pressure relief device etc. Suitable monitoring, control (operation of associated circuit breaker and isolator) and protection for LT auxiliary transformer connected to tertiary winding of auto-transformer for the purpose of auxiliary supply shall be provided. The over current and other necessary protection shall be provided for the auxiliary transformer. These protection and control may be provided as built-in feature either in the bay controller to be provided for the auxiliary system or in the control and protection IEDs to be provided for autotransformer. c) 765 kV Reactor Protection Reactor shall be provided with the following protections: Numerical Differential Protection. Numerical Restricted Earth Fault Protection Numerical Back-up impedance protection Besides these, reactors shall also be provided with Buchholz relay, Magnetic Oil Gauge (MOG) with low oil level alarm, protection against oil and winding temperatures and pressure relief device, etc. d) Bus bar Protection The high-speed low impedance type bus bar differential protection, which is essential to minimize the damage and maintain system stability at the time of bus bar faults, shall be provided for 765 kV and 400 kV buses. Duplicated bus bar protection is envisaged for REC Power Development and Consultancy Limited 160RFP for Selection of Bidder as Transmission Service Provider 765 kV and 400 kV bus-bar protection. Bus bar protection scheme shall be such that it operates selectively for each bus and incorporate necessary features required for ensuring security. Bus Bar protection system for new substation shall be de-centralized (distributed) type. The scheme shall have complete bus bar protection for present as well as envisaged future bays i.e. input/ output modules for future bays for the bus sections under present scope shall be provided. Peripheral Units (PUs) shall be provided by the respective bay owners. In case, the bus section is provided, then each side of bus section shall have separate set of bus bar protection schemes. For existing substations, the existing bus bar protection shall be augmented as per requirement. e) Local Breaker Back up Protection This shall be provided for each 765 kV and 400 kV circuit breakers and will be connected to de-energize the affected stuck breaker from both sides. Notes: 1. LBB and REF relays shall be provided separately from transformer differential relay. 2. LBB relay may also be provided as built-in protection function of distributed bus bar protection scheme; however in such case separate LBB relay shall be provided for tie bays (in case of One and Half breaker scheme). 3. Over fluxing and overload protection can be provided as built-in feature of differential relay. 4. In 765 kV and 400 kV switchyard, if spare bay of half diameter is identified as future, Tie CB relay panel shall be with Auto-reclosure feature. B.2.6 Substation Automation System a) For all the new substations, state of art Substation Automation System (SAS) conforming to IEC-61850 shall be provided. The distributed architecture shall be used for Substation Automation System, where the controls shall be provided through Bay Control Units. The Bay Control Unit is to be provided bay wise for voltage level 220 kV and above. All Bay Control Units as well as protection units are normally connected through an Optical fibre high speed network. The control and monitoring of circuit breaker, dis-connector, re- setting of relays etc. can be done from Human Machine Interface (HMI) from the Control Room. The functions of control, annunciation, disturbance recording, event logging and measurement of electrical parameters shall be integrated in the Substation Automation System. REC Power Development and Consultancy Limited 161RFP for Selection of Bidder as Transmission Service Provider At the new substations, the Substation Automation System (SAS) shall be suitable for the operation and monitoring of the complete substation including proposed future bays/elements. In the existing substations with Substation Automation System (SAS), augmentation of existing SAS shall be done for bays under the present scope. In the existing Substations where Substation automation is not provided, control functions shall be done through control panels. Necessary gateway and modems (as required) shall be provided to send data to RLDC/SLDC as per their requirement and shall be provisioned with 2+2 redundancy i.e. 2 channels for Main Control Centre and 2 channels for Backup Control Centre. In order to meet this requirement, suitable redundancy at port and card level need to be ensured by the TSP to avoid any single point of failure which may lead to interruption in real-time grid operation. Accordingly, all the hardware for communication services of station as stated above shall support dual redundancy for data transmission of station to respective main and backup RLDCs. Any augmentation work at RLDC/SLDC is excluded from TSP’s scope. However, all the configuration work at substation end required to send data to RLDC/SLDC shall be in the scope of TSP. b) Time Synchronization Equipment Time Synchronization Equipment complete in all respect including antenna, cable, pro- cessing equipment required to receive time signal through GPS/NavIC or from National Physical Laboratory (NPL) through INSAT shall be provided at new substations. This equipment shall be used to synchronize SAS and IEDs etc. B.3.0 Substation Support Facilities Certain facilities required for the operation and maintenance of substations as described below shall be provided at the new substation. In existing substation, these facilities have already been provided and shall be extended/ augmented as per requirement. B.3.1 AC and DC power supplies For catering the requirements of three phase and single phase AC supply and DC supply for various substation equipment (for present and future scope), the following arrangement is envisaged: i) For LT Supply at each new Substation, two (2) Nos. of LT Transformers (minimum 800 kVA for substations with highest voltage rating as 765 kV) shall be provided which shall be fed from two independent sources as per the CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007. REC Power Development and Consultancy Limited 162RFP for Selection of Bidder as Transmission Service Provider Metering arrangement with Special Energy Meters (SEMs) shall be provided by TSP at 33 kV tertiary of Transformer for drawing auxiliary supply at new substation. Such SEMs shall be provided by CTU at the cost of the TSP. Accounting of such energy drawn by the TSP shall be done by RLDC/RPC as part of Regional Energy Accounting. Additionally, Active Energy Meters may be provided at the same point in the 33 kV tertiary of Transformer by local SEB/DISCOM for energy accounting. ii) 2 sets of 220V battery banks for control and protection and 2 sets of 48 V battery banks for PLCC/ communication equipment shall be provided at each new Substation. Each battery bank shall have a float-cum-boost charger. At new substation, sizing of 220 V battery and battery charger shall be done based on the number of bays specified (including future bays) as per CEA Regulations and relevant IS. 2 sets of 48 V battery banks for PLCC and communication equipment for present and future scope shall be provided at each new Substation with at least 10-hour battery backup and extended backup, if required. 48 V DC can be achieved from 220 V DC battery bank using adapter, if so desired by TSP, without compromising backup time. iii) Suitable AC and DC distribution boards and associated LT Switchgear shall be provided at new substation. For new substation, following switch boards shall be considered with duplicate supply with bus coupler/ sectionalizer and duplicate outgoing feeders except for Emergency lighting distribution board which shall have only one incoming feeder: (a) 415 V Main Switch board – 1 No. (b) AC distribution board – 1 No. (c) Main lighting distribution board – 1 No. (d) Emergency lighting distribution board – 1 No. (e) 220 Volt DC distribution board – 2 Nos. (f) 48 Volt DC distribution board – 2 Nos. Sizing of LT Switchgear shall be suitable to cater the requirement for all present and future bays. AC and DC distribution boards shall have equipped modules for all the feeders (including future as specified). iv) At new Substation, one No. of DG set (minimum 500 kVA for substations with highest voltage rating as 765 kV) shall be provided for emergency applications. v) For substation extensions, existing facilities shall be augmented as required. B.3.2 Fire Fighting System Fire-fighting system for substation including Transformer and Reactor shall conform to CEA (Measures Relating to Safety and Electric Supply) Regulations, 2023 as amended from time to time. Further, adequate water hydrants and portable fire extinguishers shall be provided in the substations. The main header of the firefighting system shall be suitable for extension to REC Power Development and Consultancy Limited 163RFP for Selection of Bidder as Transmission Service Provider bays covered under the future scope; necessary piping interface in this regard shall be provided. Optical Beam type heat detection for GIS hall fire protection system shall be provided for all the GIS halls. At existing substations, the fire-fighting systems as available shall be extended to meet the additional requirements. B.3.3 Oil Evacuating, Filtering, Testing and Filling apparatus To monitor the quality of oil for satisfactory performance of transformers, shunt reactors and for periodical maintenance necessary oil evacuating, filtering, testing and filling apparatus would be provided at new substations. Oil storage tanks of adequate capacities for storage of transformer oil would be provided. Online Transformer Oil Drying Out System (TODOS) shall be provided in line with the provisions of Standard Specification and Technical Parameters for Transformers and Reactors (66 kV and above Voltage Class) as amended up to date available on CEA website. B.3.4 Illumination Normal and emergency AC and DC illumination shall be provided adequately in the control room and other buildings of the substation. The switchyard shall also be provided with adequate illumination. The lighting of the entire control room building, fire-fighting pump house, other building (if any) and switchyard shall be done by LED based low power consumption luminaries. B.3.5 Control Room For the new substation, substation control room shall be provided to house substation work stations for station level control (SAS) along with its peripheral and recording equipment, AC and DC distribution boards, DC batteries and associated battery chargers, Fire Protection panels, Telecommunication panels and other panels as per requirements. Air conditioning shall be provided in the building as functional requirements. Main cable trenches from the control room shall have adequate space provision for laying of cables from the control room for all the future bays. At existing substations, the adequacy of size of control room shall be ascertained and the same shall be augmented as per requirement. B.3.6 GIS hall The Gas Insulated Switchgear (GIS) of each voltage level along with other associated equipment shall be housed inside separate GIS building. The panels i.e. Bay level units, REC Power Development and Consultancy Limited 164RFP for Selection of Bidder as Transmission Service Provider bay mimic, relay and protection panels, RTCC panels, PLCC panels, panels for tele- communication system etc. are to be placed in a separate room in the GIS building. The size of the room shall be such that all the panels for the bays under present scope shall be accommodated. The panel room shall be air-conditioned. Further, the temperature of the room shall be monitored through substation automation system by providing necessary temperature transducers. Ventilation system of suitable capacity shall be provided for each GIS hall. GIS hall shall be constructed in such a way that its extension does not cause any hindrance to accommodate the bays of future expansion of substation. One EOT Crane of suitable capacity for erection and maintenance of largest GIS component/assembly and all plant installed in the GIS switchgear room shall be provided in each GIS hall. The crane shall be capable of fulfilling all special requirements for erection and maintenance of GIS equipment. The capacity of the crane shall be sized to lift the heaviest GIS switchgear component. For extension of existing GIS, existing facilities shall be suitably augmented/ extended for GIS equipment under present scope. B.3.7 Control Concept All the EHV circuit breakers in substation/switching stations shall be controlled and synchronized from the switchyard control room/remote control center. All the isolators shall have control from remote/local whereas the earth switches shall have local control only. B.3.8 Visual Monitoring System (VMS) for watch and ward of substation premises: Visual Monitoring System for effective watch and ward of substation premises shall cover all the transformers and reactors, all other major AIS Equipment (such as CB, isolators, CT, CVT, SA etc. as applicable) , GIS bays, panel room, all the gates of switchyard and all entry and exit points of control room building and accordingly the location of cameras shall be decided. In addition to the gates of the switchyard, the cameras shall also be located around the boundaries at suitable locations. The camera shall be high-definition color CCD camera with night vision feature. The VMS data partly/completely shall be recorded (minimum for 15 days) at least @25fps (or better) and stored on network video recorder. The system shall use video signals from various cameras installed at different locations, process them for viewing on workstations/monitors in the control room and simultaneously record all the cameras. The VMS data should go only to the intended personnel/facility and not to the remote server of the Camera (VMS supplier). Mouse/keyboard controllers shall be used for pan, tilt, zoom and other functions of the desired camera. The Visual Monitoring System shall have provision of WAN connectivity for remote monitoring. All camera recordings shall have Camera ID and location/area of recording as well as date/time stamp. The equipment should generally conform to Electromagnetic compatibility requirement for outdoor equipment in EHV substation. REC Power Development and Consultancy Limited 165RFP for Selection of Bidder as Transmission Service Provider Advisory on deployment of CCTV issued by Ministry of Electronics and Information Technology (MEITY) shall be followed. At existing substations, the Visual Monitoring System if available shall be augmented as per existing or better specification as required. B.4 General Facilities a) Line Gantry/Towers are envisaged for bays under the present scope only. However, for adjacent future line bay, gantry/tower shall be designed for extension (considering Hexa conductors for 765 kV, Quad conductors for 400 kV and Twin conductor for 220 kV future lines) wherever applicable. b) Bay extension works at existing substation shall be executed by TSP in accordance with the requirements/provisions mentioned above. However, interface points shall be considered keeping in view the existing design/arrangement at the substation. c) TSP has to arrange for construction power and water on its own. d) All outdoor steel structures including anchor/foundation bolts shall be fully galvanized. The weight of the zinc coating shall be at least 610 g/m2, however, for coastal/creek regions it shall be at least 900 g/m2. (if applicable) e) In 765 kV and 400 kV switchyard, if spare bay of half diameter is identified as future, all the equipment for Tie and Future bay shall be designed considering the current rating of line bay i.e. 3150 A. f) Boundary wall shall be brick masonry wall with RCC frame or Stone masonry wall or Precast RCC wall under present scope along the property line of complete substation area including future switchyard area to prevent encroachment and unauthorized access. Minimum height of the boundary wall shall be of 1.8 m from Finished Ground Level (FGL). g) All electrical equipment shall be installed above the Highest Flood Level (HFL) and where such equipment is not possible to be installed above Highest Flood Level, it shall be ensured that there is no seepage or leakage or logging of water. h) As per CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022 /CEA Manual on Transmissions Planning criteria 2023, line approaching substation shall normally be perpendicular to the REC Power Development and Consultancy Limited 166RFP for Selection of Bidder as Transmission Service Provider substation boundary for a stretch of 2-3 km. Accordingly, TSP shall ensure that line terminations at substations are arranged in a manner to avoid hindrance to future line terminations at the substations. i) TSP shall finalize the substation site/layout such that the corridor for the termination of lines, including future lines at the substation, can be accommodated without any constraints. Accordingly, forests, large water bodies, or hills adjacent to the substation boundary should be avoided. B.5 EXTENSION OF EXISTING SUBSTATION The following drawings/details of existing substation are attached with the RfP documents for further engineering by the bidder. Sl. No. Drawing Title Drawing No./Details Rev. No. A. 765 kV Srikakulam S/s (GIS) 1.0 Single Line Diagram NHVS-EMC-SRKL-E-LAY- 3 DRG-001 ZF15-800 (50-9) 5KBJ.449.704 2.0 General Arrangement GA/Srikakulam 3.0 Earthmat Layout NHVS-EMC-645-SRKL-E- 0 ERT-DRG-002 4.0 Visual Monitoring System 5.0 Bus Bar Protection Schneider-Centralized bus bar scheme 6.0 Substation Automation Schneider Make (SCE Version: System (SAS) 4.85.06) B. 765 kV Warangal New S/s (AIS) 1.0 Single Line Diagram 5427PS102-WGL-E-SYD- R3 SYS-0001-SL 2.0 General Arrangement 5427PS102-WGL-E-SYD- R7 0001-GA 3.0 Earthmat Layout 5427PS102-WGL-E-SYD- R0 SYS-0005-EW 4.0 Visual Monitoring System 5.0 Bus Bar Protection Make: GE Model: Micom 741 6.0 Substation Automation 5427PS102-WGL-U-SYD- A System (SAS) SAS-0013-AR C. 400 kV Khammam S/s (AIS) 1.0 Single Line Diagram C/Engg/Khammam_Extn/SLD 0 2.0 General Arrangement Attached - REC Power Development and Consultancy Limited 167RFP for Selection of Bidder as Transmission Service Provider 3.0 Earthmat Layout - - 4.0 Visual Monitoring System 5.0 Bus Bar Protection 6.0 Substation Automation System (SAS) B.5.1 The existing drawings provided above and in subsequent amendments to the RfP are as received from the developer of existing substation and provided only for reference. Bidders shall follow the RfP for scope of work. Actual site conditions may be different due to other schemes being executed or subsequent revisions by the developer. Thus, Bidders are advised to visit the substation sites and acquaint themselves for details such as: i. Actual site conditions, Layout, Topography ii. Infrastructure such as roads, cable trench, drainage iii. Space availability in existing control room and LT panel room iv. Soil investigation v. Fire hydrant layout vi. SAS architecture and IO list vii. Boundary viii. Design philosophy etc. LOCATION DETAILS OF EXISTING / PLANNED SUBSTATIONS a) Pendurthi 765/400 kV GIS: New substation which is to be implemented under present scheme b) Khammam-II 765/400 kV S/s: New substation which is to be implemented under present scheme c) Khammam 400/220 kV S/s: 17°21'57.57"N, 80°14'14.60"E d) Srikakulam 765/400 kV GIS S/s: 18°48'26.16"N, 84°27'9.01"E e) Warangal New 765/400 kV S/s: 17°48'57.02"N, 79°25'28.05"E Note: The above coordinates/location of substation indicated is approximate in the substation area. Exact coordinates for the corresponding bays/gantry for termination of the respective line may be verified & finalized in coordination with actual site. REC Power Development and Consultancy Limited 168RFP for Selection of Bidder as Transmission Service Provider SPECIFIC TECHNICAL REQUIREMENTS FOR STATCOM The proposed STATCOMs shall be conforming to the requirements of CEA (Technical Standards for Connectivity to Grid) Regulations, 2007 including amendments and CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Other CEA Regulations and MoP guidelines, as applicable, shall also be followed and complied with. Note: These specifications are general in nature applicable to a STATCOM in combination of MSC and MSR. Since, +300 MVAr STATCOM along with 2x125 MVAr MSC has been specified under the present Scope of work at Pendurthi (Vizag) GIS, the specification may be read accordingly. C.1 Introduction: This technical specification for a STATCOM Station consists of STATCOM MSCs (Mechanically Switched Capacitors) and MSRs (Mechanically Switched Reactors) (to be installed at MV bus) including associated coupling Transformer (rated 400/xx kV) and other equipment connected to the 400 kV bus. MV voltage level (xx kV) of the coupling Transformer can be chosen by the TSP to optimize the offered solution which meets functional requirement of this Technical Specification. The STATCOM station shall operate asymmetrically in the leading and lagging MVAr regions as applicable to reach the dynamic range specified. The purpose of the STATCOM station is to regulate the voltage of 400 kV Bus Point of Common Coupling (PCC). The Configuration and the nominal rating of the STATCOM station is specified in this document. The main building block of the STATCOM should be single phase Voltage Source Converter (VSC) based convertor valve (multi-level) operating in a way to eliminate or minimize AC filter requirement to High pass filter only and connected to the xx kV bus through air core reactors. The ± 300 MVAr STATCOM with 2x125 MVAr Mechanically switched Capacitor (MSC) shall be with control switching arrangement for 330 MVAr, 765 kV. C.1.1 Definitions and Abbreviations For the purpose of this specification, the following definitions / abbreviations are used: PCC: Point of Common Coupling (herein also called as Point of Interconnection (POI)) The connection point between the STATCOM and the ISTS at which performance requirements are defined. Reference Voltage (Vref): The Point on the voltage/current (V/I) characteristics where the static synchronous compensator (STATCOM) is at zero output (i.e. where no REC Power Development and Consultancy Limited 169RFP for Selection of Bidder as Transmission Service Provider reactive power is absorbed from, or supplied to, the transmission system where the voltage is controlled) MV: Medium Voltage. STATCOM Unit: Static Synchronous Compensator based on Multi-Module technology and including air cored reactors as needed, Valve cooling, switchgear and its control and protection. STATCOM: Static Synchronous Compensator consisting of STATCOM Unit(s) connected to a common Coupling Transformer. A static synchronous generator operated as a shunt connected compensator, whose capacitive or inductive output current can be controlled independently of the AC system voltage. MSC: Mechanically Switched Capacitor (Including Switchgear). A shunt-connected circuit containing a mechanical power-switching device in series with a capacitor bank and a current limiting reactor. MSR: Mechanically Switched Reactor (Including Switchgear). A shunt-connected circuit containing a mechanical power-switching device in series with a reactor. Sub Module: Basic single power module of a Multi Module STATCOM unit Valve. It is a Part of a STATCOM unit valve comprising controllable switches and diodes connected in full bridge arrangement, together with their immediate auxiliaries, and storage capacitor, if any, where each controllable switch consists of one or more switched valve device(s) connected in series. Valve: Electrically and mechanically combined assembly comprising of forced commutated devices [for example insulated-gate bipolar transistor(IGBT)] assembled in levels, complete with all connections, auxiliary components, and mechanical structures, which can be connected in series with each phase of the reactor of a STATCOM unit. Valve Section: Electrical assembly defined for test purposes, comprising one of several sub-modules. Valve Structure: Physical structure holding valve(s), which is insulated to the full system voltage above earth potential. STATCOM Station: STATCOM Station includes 400 kV Switchgear, Coupling Transformer, STATCOM, MSCs (as applicable), MSRs (as applicable) along with its switchgear and complete integrated control and protection whose outputs are coordinated. (Complete turnkey delivery at site). CT: Current Transformer. VT: Voltage Transformer. SAS: Substation Automation System. Response Time: the duration from a step change in control signal until the voltage changes by 90% of its final change, before any overshoot. REC Power Development and Consultancy Limited 170RFP for Selection of Bidder as Transmission Service Provider Settling Time: The duration from a step change in control signal input until the STATCOM output settles to within +5% of the required control output. Slope: The ratio of the voltage change to the current change over a defined controlled range of the STATCOM, normally the full (inductive plus capacitive) range at nominal voltage, expressed as a percentage. VSC: Voltage Source Convertor, A forced commutated device (for example, IGBT) based self-commutated convertor that is capable of generating AC voltage from DC capacitor. Voltage/Current (V/I) Characteristic: The relationship between the current of the STATCOM and the voltage at the point of connection. Lagging Operation: Inductive operation or reactive power absorption of the STATCOM similar to a shunt reactor. Leading Operation: Capacitive operation or reactive power generation of the STATCOM similar to a shunt Capacitor. TSP: Transmission Service Provider C.2 Relevant Standard: STATCOM Station shall comply with the following standards (latest edition): Sl. No. Description Standards 1 Voltage source converter (VSC) valves for IEC- 62927 STATCOM IEEE- 1052 IEC-60747 2 Control, protection and monitoring IEC-61000 IEC-60255 3 Valve Hall for housing the equipment as above IEC-60071 comprising of: IEC-60270 - wall bushings for connection between IEC-60137 converter phases and decoupling reactors, - piping and tubing connections of the cooling system to converter - connection of the control cabinet with the converter through optical fibers - internal lighting, auxiliary power supply (AC and DC) and power socket system - internal HVAC system 4 X kV, dry insulated, air core and air self-cooled IEC- 60076 decoupling reactors. Mechanically Switched Reactors (MSRs), half-reactors stacked on above REC Power Development and Consultancy Limited 171RFP for Selection of Bidder as Transmission Service Provider Sl. No. Description Standards the other, Outdoor installation, Complete with supporting structures 5 Power Capacitors (MSC etc.) IEC-60871-1 6 400 kV Power transformer (Coupling IEC-60076 Transformer) IEC-60354 7 CT’s and VT’s IEC- 61869 8 Dis-connectors and Earthing Switches IEC- 62271 9 HV and MV Circuit Breakers IEC- 62271 10 Surge Arresters IEC- 60099 11 Auxiliary and grounding transformer IEC- 60076 IEEE C57.32 IS- 5553 (Part 6) 12 Neutral Grounding Resistor, charging resistor IEEE- C57.32 13 UPS, SMPS and Other Power supply units IEC- 62040 IEC- 61558 14 Cyber Security IEC-62243 C.3 Scope of work for STATCOM The scope of work with regard to the works associated with the STATCOM shall comprise ±300 MVAr Modular Multi-level Voltage Source Converter (MMC-VSC) based STATCOM along with 2x125 MVAr MSC (Mechanically Switched Capacitor). STATCOM can either be Single/ multiple units. The minimum size of a unit allowed is 150 – 200 MVAr. TSP shall ensure that there are no coordination issues between multiple STATCOM branches of STATCOM station. Further complete Dynamic range for STATCOM may also be installed based on appropriate studies instead of combination of VSC with MSC/MSR technology. MV bus voltage is to be decided by OEMs. The TSP shall be responsible for the complete installation of STATCOM station along with the substation works as specified in the complete scope of work. The TSP shall also perform the system studies (steady state and dynamic) according to the requirement mentioned and documentation of the same shall be preserved by TSP and to be submitted to CEA/CTU/GRID-INDIA, as per their request. TSP shall carry out a detailed study on prevailing system conditions before interconnection of the STATCOM to assess the performance of the STATCOM. Parameters tuning to avoid any adverse impact on the grid with integration of the STATCOM shall also be identified and implemented at this stage. TSP shall carry out tuning of Power Oscillation Damping (POD) along with an interaction study with nearby HVDC/FACTS controllers. REC Power Development and Consultancy Limited 172RFP for Selection of Bidder as Transmission Service Provider TSP shall ensure interconnection study at the time of commissioning and shall also be responsible for tuning the POD during the license period as per relevant standards (e.g. IEEE 1052). The switchgear for connection of STATCOM units MSCs and MSRs provided on the secondary side of the coupling transformer shall be of standard voltage rating as per relevant IEC. The switchgear, structure, control, protection and substation automation on the 400 kV side shall be as per applicable Technical Specification of the substation equipment. Generally, the purpose of STATCOM is to improve system stability, provide damping, and smooth out the step voltage change associated with MSCs, MSRs and external compensating equipment (i.e. any existing capacitor and reactor banks) switching and provide steady state VARs as needed to support the 400 kV bus voltage. In order to get optimum control of MVAr, the control of MSCs and MSRs, as well as reactor banks connected on the 400 kV HV side, may be integrated along with STATCOM control to provide steady state 400 kV bus voltage control in a smooth manner. MSRs and MSCs are to be switched to relieve the STATCOM from high level operation, reduce its continuous losses and maximize its dynamic control potential. There should be a provision for the independent operation of MSC/MSR after delinking it with STATCOM controls when STATCOM is out of service due to any reason. Switching of MSC/MSR shall be based on value of external bus voltage. The operating functions of the STATCOM Station shall include:  Steady state voltage control of 400 kV bus,  Balance steady state voltage at 400 kV bus,  Dynamic over-voltage control,  Transient and Dynamic stability control  Damping of Power Oscillations It is assumed that the arresters will limit any transient and switching surge over voltages and may also, by design, limit dynamic over voltages. The requirement of reactive power compensation (as defined above) guaranteed by the TSP shall not be less than the levels specified considering following.  The total cumulative Capacitive (+) and Inductive (-) MVAr rated Capacity of STATCOM Station as defined above comprising of STATCOM, MSCs (as applicable), MSRs (as applicable) coupling transformer, coupling reactor or any filter (if applicable) shall be rated at 1 p.u. voltage, for the frequency range of 48.5 Hz-50.5 Hz and at 50 o -C (Celsius) ambient temperature at 400 kV Bus (Referred to as “Point of Common Coupling” or PCC). REC Power Development and Consultancy Limited 173RFP for Selection of Bidder as Transmission Service Provider  Capacity of one or more branches of MSC, MSR in STATCOM Station can be included in the STATCOM with equivalent capacity. Accordingly, ratings of STATCOM Unit/Branch equipment may be designed. Example of equivalent acceptable solutions for each STATCOM Station is given below: For ±300 MVAr STATCOM: Option 1: ±300 MVAr STATCOM, 2x125 MVAr Mechanically switched Capacitor (MSC). Option 2: +425/-300 MVAr STATCOM, 1x125 MVAr Mechanically switched Capacitor (MSC). Option 3: +550/-300 MVAr STATCOM  The rated capability of STATCOM, MSC (as applicable) and MSR (as applicable) shall be at 400 kV (Referred to as “Point of Common Coupling” or PCC) and in the steady state frequency range of 48.5 Hz-50.5 Hz.  The STATCOM Station including STATCOM Units, MSCs and MSRs shall be designed to operate continuously under the worst possible combination of steady state voltage range of 360-440 kV and frequency range of 47.5 Hz – 52.5 Hz respectively and transient and temporary over voltages defined in Clause C.6.1-f).  The AC voltage unbalance at fundamental frequency shall be assumed equivalent to a negative phase sequence component of 1.5% for equipment rating purposes.  The reactive power compensation levels shall be determined by manufacturing tolerances of the components and measurements carried out using metering accuracy instrumentation at the 400 kV feed points to the STATCOM Station.  The reactive power capability shall also be determined by calculations based on test values of appropriate quantities at the discretion of the owner.  In calculations of capability and availability, the owner shall assume the most unfavorable combinations of control, manufacturing and measurement tolerances.  In case more than one STATCOM Station are installed in a particular substation, each STATCOM Station shall be connected to 400 kV bus individually with complete separate downstream system. Each individual STATCOM station shall have complete independent yet coordinated control system to avoid simultaneous tripping of both STATCOM Stations. The system shall be design in such a way REC Power Development and Consultancy Limited 174RFP for Selection of Bidder as Transmission Service Provider that single common contingency (other than loss of 400 kV voltage, abnormal system events) will not cause tripping of both STATCOM Stations.  Operation of STATCOM Station shall not excite any resonance condition in connected Power System.  Control of STATCOM Station shall be designed to prevent hunting between MSRs, MSCs and STATCOM. C.3.1 STATCOM building The STATCOM station shall have an independent building including a separate control room different from the main control room building of the 765/400 kV Substation. The STATCOM Building shall comprise of following facilities: 1. Control and Relay Panel room 2. ACDB and DCDB room 3. Battery room 4. Service Room cum workshop 5. Conference room 6. Valve hall 7. Cooling system room 8. Lobby 9. Corridor with minimum width of 1600 mm 10. Portico 11. Common Toilet 12. Provision of shaft for electrical, sanitary, water supply facilities 13. Other facilities as per functional requirement of building 14. AHU Room C.4 Ambient Condition STATCOM Station should be designed to perform at 50 °C ambient temperature. C.5 Power System Characteristic The following AC power system characteristics apply at the point of connection i.e. point of common coupling in this case (PCC). STATCOM station operation is required within the parameter value and duration given in following table: S. No Power System Characteristic Value unit 1. Nominal ac system voltage, line-to-line 400 kV 2. Maximum continuous ac system voltage, line 420 kV to-line REC Power Development and Consultancy Limited 175RFP for Selection of Bidder as Transmission Service Provider S. No Power System Characteristic Value unit 3. Minimum continuous ac system voltage, line 380 kV to-line 4. Maximum short-term ac system voltage, line 448 kV to-line 5. Maximum duration of item 4 10 s 6. Continuous negative-sequence voltage 1 % component (used for performance calculation) 7. Continuous negative-sequence voltage 1.5 % component (used for rating calculation) 8. Continuous zero-sequence voltage component 1 % 9. Nominal ac system frequency 50 Hz 10. Maximum continuous ac system frequency 50.5 Hz (for rated output) 11. Minimum continuous ac system frequency 48.5 Hz (for rated output) 12. Maximum short-term ac system frequency 52.5 Hz 13. Minimum short-term ac system frequency 47.5 Hz 14. Basic Insulation Level (BIL) 1550 kV peak 15. Switching impulse level (SIL) 1050 kV peak 16. Power Frequency Withstand voltage 630 kV 17. Maximum three-phase fault current a) for performance requirements a) 63 kA b) for rating of STATCOM b) 63 kA for 1s X/R (Positive/Negative Seq)* 4 X/R (Zero Seq)* 5 Clearing time - normal 0.1 s Clearing time – backup 0.75 s 18. Maximum three-phase fault current 63 kA 19. Minimum three-phase fault current # -for performance requirements 26 kA -for safe operation 26 kA 20. Maximum single-phase fault current 63 kA REC Power Development and Consultancy Limited 176RFP for Selection of Bidder as Transmission Service Provider S. No Power System Characteristic Value unit 21. Minimum single-phase fault current# 12 kA Harmonic impedance sectors for each Chapter 7.3 of CIGRE 22. harmonic number up to the 49th harmonic Publication 139 or system impedance data as R-X values with frequency steps not larger than 1 Hz (for performance and/or STATCOM system component rating) Background harmonic voltage (or current) 23. 5th Harmonic 1.5% spectrum (for STATCOM components 7th Harmonic 1.0% rating) (Distortion up to 15th Harmonic Other Harmonics 0.5% (each) 24. Power System Phase Rotation CCW The STATCOMs shall remain connected to the grid and shall be able to operate at rated reactive power capability when voltage at the interconnection point, on single phase or three phases dips up to the level depicted by the thick lines in the following curve (for specified time) and up to at least 0.3 p. u. in case of two phase faults: VT : Actual Voltage; Vn: Nominal Voltage REC Power Development and Consultancy Limited 177RFP for Selection of Bidder as Transmission Service Provider C.6 STATCOM Station Characteristics Figure-1: Conceptual Indicative Schematic diagram of STATCOM Station Figure-2: VI Curve of the VSC Portion REC Power Development and Consultancy Limited 178RFP for Selection of Bidder as Transmission Service Provider Figure-3: VI Curve of the STATCOM Station C.6.1 STATCOM Station Ratings The output of a STATCOM Station shall be adjusted continuously over the range illustrated in Figure-3. The following items define the ratings of the STATCOM station equipment. a) The STATCOM Station should regulate the voltage of 400 kV bus to a reference voltage of 400 kV (1.0 per unit, Point L Figure-3), continuously adjustable between 0.95 per unit and 1.05 per unit. b) The nominal capacitive and inductive reactive power output of the STATCOM should be as defined in the scope, at 1.0 p.u. AC bus voltage and nominal system frequency (f), and 50°C ambient temperature (Point A and point B of figure-2). c) The slope of the STATCOM Station characteristic should be adjustable in steps of not greater than 0.5% between 1% and 8%, on a basis of cumulative MVA capacity of STATCOM Station (A+B in Figure-3). d) The STATCOM Stations shall continue to inject reactive power during temporary under voltage down to 60 kV (0.15 p.u. for the duration 0.3 sec (Point C) and STATCOM behavior for voltages above 0.15 p.u. shall be as specified under section C.5 above, The STATCOM system may be blocked if the under voltage persists for time beyond limits specified under section C.5 above. e) The STATCOM shall continue to absorb reactive power during HVRT Conditions in a controlled manner as per the following. REC Power Development and Consultancy Limited 179RFP for Selection of Bidder as Transmission Service Provider Minimum time for remaining connected to the Nominal Voltage (pu) Grid V > 1.50 Instantaneous trip 1.50 ≥ V > 1.30 100 milli seconds 1.30 ≥ V > 1.10 10 seconds V ≤ 1.10 Continuous STATCOM Station may be tripped if the respective temporary over voltages as mentioned above persists for more than its respective mentioned duration. f) The STATCOM Station should be capable of repeating temporary operation as defined in any one of item (d) and (e) as above for at least 3 charging cycles in 60 mins. g) The coupling transformer and all bus equipment, such as filter branches (if applicable), MSC and MSR branches etc. and the MV Bus should be rated to withstand the specified continuous and short-term operation, and to withstand or be protected against voltage and current stresses that exceed these conditions. h) All equipment in the STATCOM Station should be capable of sustaining, without damage, any fault limited by the maximum design short circuit level of the system and the Coupling transformer impedance. i) The TSP shall assume the negative sequence voltage of 1% at rated short circuit level and provide control to reduce this unbalance. j) The injected harmonics by STATCOM Station under the full operating range measured at 400 kV Bus (PCC) in accordance with IEEE standard. k) The STATCOM controls should be designed to correct negative sequence voltage during steady state operation. l) The switching module design should include an appropriate allowance for stray capacitance and component tolerances. m) The STATCOM should be designed to prevent, or alternatively to withstand, false firing events, i.e., the firing of any valve at an incorrect time in the cycle or when not ordered. C.6.2 Control Objectives The control system shall control the STATCOM, MSCs, MSRs required under this specification, as well as all bus reactors on the 400 kV HV bus of the substation. Operation logic for the breakers, disconnectors and earth-switches in the STATCOM Station shall also be incorporated in the control system. The control shall be programmable and shall have sufficient scope and flexibility (software programming margin of at least 20%) to permit re-programming according to future changes/addition REC Power Development and Consultancy Limited 180RFP for Selection of Bidder as Transmission Service Provider in the power system. The operator interface must be integrated in a latest version of Windows environment. C.6.2.1 STATCOM Station Functions and Applications C.6.2.1.1 Voltage Control mode (Automatic and Manual) Control of the positive sequence component of the fundamental frequency voltage in steady state at POI shall be, with slope in the range as specified at clause 6.1 (c) above. There shall be following provisions in STATCOM System to operate in Voltage Control Mode: a) To adjust the reference voltage for changes by Grid Operator. b) To adjust the value of reactive power drop in p.u. to provide a stable, coordinated and dynamic response. c) To adjust the voltage dead band with a minimum magnitude of ±0.05 p.u. C.6.2.1.2 Fixed Reactive Power Mode In this mode, the STATCOM system shall maintain a specified constant reactive power output at the POI under continuous / steady state operating region. The target reactive power level and mode (injection or absorption) shall be specified by the Grid operator. There shall be a provision to adjust the reactive power set point. The dynamic response of the STATCOM system to any changes in reactive power shall be positively damped with a damping ratio of 0.3 or better. C.6.2.1.3 Steady State Condition The STATCOM Station (STATCOM along with MSCs and MSRs) shall provide necessary reactive power support to the 400 kV bus (PCC) to compensate for voltage variation under steady state. C.6.2.1.4 Dynamic Over-voltage Control Performance The STATCOM shall be required to provide necessary reactive power support with fast and smooth variation so that over-voltages under dynamic conditions are controlled. STATCOM shall smooth out the step caused by the switching of MSCs and MSRs. The operation of each STATCOM over its range of MVAr from full capacitive to full Inductive capacity and vice-versa shall be on the basis of smooth variation. C.6.2.1.5 Transient and Dynamic Stability Performances REC Power Development and Consultancy Limited 181RFP for Selection of Bidder as Transmission Service Provider The STATCOM Station shall provide necessary reactive power so that the transient and dynamic stability of the Owner’s system is enhanced. C.6.2.1.6 Damping of Power Oscillations The STATCOM shall provide necessary damping to power oscillations by modulating its output in its entire range based on the measured rate of change of power/frequency at the 400 kV bus. The damping controller would track local area oscillations as well as wide area oscillations and control would include several loops each focused on different frequencies. TSP shall ensure the damping of oscillation during the entire license period including the pre–commissioning period as per relevant standards. (e.g. IEEE 1052). C.6.2.1.7 Facility for compensation of phase imbalance Provide negative phase sequence voltage control to minimize the presence of negative sequence content of the 400 kV bus voltage. C.6.2.1.8 Start up and Initial Switching The operation of STATCOM Station during start-up/initial switching on should not create significant energizing transients causing voltage drop, voltage distortion and swinging of transmission voltage angle at the PCC bus by more than +/-5%. TSP shall have to ensure this analytically during the design phase and also in the field after the commissioning of the facility. TSP shall prepare the design documentation and the same shall be preserved by TSP and to be submitted to CEA/CTU/GRID-INDIA, as per their requirement. C.6.2.1.9 Gain Supervision and Control To control the regulator gain in order to prevent oscillations and excessive overshoot in the STATCOM response, a gain supervision function shall be implemented. This shall be an essential function for the supervision of stability of closed-loop voltage control. The function of this controller is that when the supervision of the gain in the voltage regulator detects oscillations in the voltage controller output, the gain shall gradually be reduced until stability is reached. Normally it is a changed condition in the transmission system contribution to the closed loop gain that results in instability. The reduction in the voltage regulator gain shall only balance the external change. The control should be adaptive in order to maximize its effectiveness. Gain reductions should be indicated and the reduction of the gain shall be able to be reset to nominal value by means of commands from the operator interface or automatically. A relative gain factor shall also be able to be changed from a gain optimizer. C.6.2.1.10 Coordinated reactive power control of external devices To optimize the use of dynamic VARs versus steady state VARs, control of externally connected shunt capacitor or reactor banks shall be implemented. Such banks will be REC Power Development and Consultancy Limited 182RFP for Selection of Bidder as Transmission Service Provider connected locally to a HV bus or/and at MV bus. For simultaneous control with the supplementary VSC current controller, coordination for the two functions shall be provided. External devices like mechanically switched capacitors (MSC)/mechanically switched reactors (MSR) can be switched ON or OFF to position the steady state operating point of the VSC so as to extend its dynamic range. There should be a provision for independent operation of MSC/MSR after delinking it with STATCOM controls when STATCOM is out of service due to any reason. The threshold values for switching the MSC/MSR on/off shall be configurable in all modes of operation. C.6.2.1.11 Supplementary VSC current controller To optimize the use of dynamic VARs versus steady state VARs, a control function that slowly reduces or offsets the STATCOM point of operation shall be implemented. By deliberately adjusting the voltage reference setting within a narrow window the STATCOM system output is pushed towards either a specific point or towards a window to preserve dynamic range. This slow operating function is meant to provide for slower controllers, such as externally connected shunt banks to operate and meet the slower long term voltage variations caused by daily or weekly load variations. Rapid changes in the system voltage that call for dynamic compensation will have priority over this type of controller. C.6.2.1.12 Gain optimization To provide operation at optimal regulator gain, a fully automatic optimizing function shall be implemented. This function operates by inducing a small change in the STATCOM output. The gain is adjusted based on the network response signal. C.6.2.1.13 Control of Direct Current During STATCOM operations, any flow of direct current to the transformer’s MV side must be less than 25% of the transformer magnetizing current. DC current flow in the transformer should be minimized by an independent control function that minimizes DC current. For presence of up to 0.2% second harmonic in 400 kV system, the STATCOM control should minimize DC current flow in the transformer. C.6.2.2 Under Voltage Strategy It is essential that the STATCOM Station operates in a robust manner when transmission system under voltages appears. In case of single phase or three phase faults, the STATCOM units must operate unrestricted, producing its rated capacitive current for transmission system voltages down to 0.15 p.u.. In case of two phase fault, the STATCOM shall be capable to produce rated capacitive current atleast down to 0.3 p.u., however, it shall be designed to operate upto 0.15 p.u. The STATCOM must be designed to operate at transmission system under voltage, even considering that severe voltage unbalances can appear. The STATCOM must not be restricted by short term negative sequence voltages up to 1.5%, appearing in conjunction with under voltages. REC Power Development and Consultancy Limited 183RFP for Selection of Bidder as Transmission Service Provider Transmission system under voltages below 0.15 p.u. will appear in conjunction with transmission system faults. The STATCOM must ride through during faults and post fault under voltages. The minimum trip delay for the STATCOM Station, upon complete loss of the transmission system voltage shall not be less than 5 seconds. If station AC auxiliary power distribution is affected, critical loads must be fed from DC station batteries, uninterrupted power supply (UPS) without tripping the STATCOM Station. Adequate capacity must be kept in DC station batteries, UPS to feed critical loads for the smooth operation of the STATCOM Station facility. There must be redundant station battery system with each station battery system capable of delivering 100% load. At under voltage conditions for the transmission system voltage, special control strategies are activated which override the normal control modes presented above. Normally if the voltage is low, the output from the STATCOM will be capacitive. If the voltage in all three phases goes below a level, but not greater than 0.15 p.u., a special under voltage strategy may be activated that controls the STATCOM output to 0 MVAr. As soon as the voltage goes higher than 0.15 p.u., the under voltage strategy is deactivated and the normal control will be in operation (for the specified duration). The STATCOM Station must not be tripped or shut down automatically due to under voltages appearing for specified duration as specified under section C.5 above. STATCOM Station must continue to operate when AC system Voltage on any or all phases dips down to 0.15 p.u. voltage as per the characteristic given at section C.5. C.6.2.3 Over Voltage Strategy C.6.2.3.1 The TSP shall carry out dynamic stability study upfront in order to assess the dynamic overvoltage requirements. These studies shall include conditions with maximum and minimum short circuit system MVA conditions, single phase and three phase faults as well as stuck breaker, outage of the nearby generator and also with the outage of parts of the STATCOM Station. It is important that the STATCOM Station rides through temporary over voltages and not trip when it is needed the most. C.6.2.3.2 The system should be able to withstand any 3 phase, 5 cycle (100 ms) and single phase 10 cycles (200 ms) fault with consequent loss of a 400 kV double circuit line and loss of a 500 MW generator. The fault duration mentioned above corresponds to time assumed for the persistence of fault. For other system parameters refer clause 5 above (Power System Characteristics). In addition to above requirement, system contingency cases as provided in Annexure-I need to be considered and satisfied. C.6.2.3.3 The 400 kV system and equipment to which the STATCOM Station is connected is designed to withstand switching surge overvoltage up to 2.5 p.u. and power frequency over voltages up to 1.5 p.u. with initial value of the temporary overvoltage up to 2.0 p.u. REC Power Development and Consultancy Limited 184RFP for Selection of Bidder as Transmission Service Provider for 1-2 cycles. Based on arrestor coordination and under the worst case scenario the 400 kV system phase to ground peak over voltages may be expected as follows i) 650 kVp for 3 peaks ii) 575 kVp up to 5 cycles iii) 530 kVp up to 1 second iv) 475 kVp up to 10 seconds a) The STATCOM Station shall be designed to withstand these sequential over voltages. b) If the over voltages greater than 1.1 p.u. are exceeded in magnitude and duration due to any system contingencies, suitable control action shall be taken by STATCOM Station to bear this kind of contingency. c) The TSP shall evolve the insulation co-ordination of the components of the STATCOM Station after studies have been conducted to determine the over- voltage profile with the STATCOM connected to the system. d) The TSP shall ensure that STATCOM Station will not excite ferro-resonance and sub- synchronous oscillation in the AC system. The study report in this regard shall be preserved and to be submitted to CEA/CTU/GRID-INDIA, if required. e) It may also be noted that the tripping action for 400 kV lines is initiated if the overvoltage exceeds 1.1 p.u. for 10 seconds. The tripping of 400 kV lines is initiated if 1.5 p.u. voltage persists for more than 100 milli seconds. The over voltage strategy shall be coordinated with these settings such that the STATCOM Station rides through up to these levels. C.6.2.4 STATCOM Station Overload / Over Current The overvoltage cycles mentioned in clause 6.2.3.3 above create a corresponding current overload in the STATCOM Station components; the STATCOM Station and its components shall be designed to withstand these. In addition to the above the STATCOM Station and its components shall be designed to withstand overloading caused due to the following eventualities. i) Short circuits and ground faults in the 400 kV system especially those occurring near the STATCOM Station and medium voltage bus of the STATCOM Station. ii) Transient overvoltage due to switching operations and atmospheric effects. iii) Temporary over voltages. iv) Short circuits in the transformer secondary circuit such as:  Bushing terminal fault  Flashover across a reactor, Bus Bar and other connected components/switchgear etc. v) Protection system faults. REC Power Development and Consultancy Limited 185RFP for Selection of Bidder as Transmission Service Provider If the rated overvoltage is exceeded as a result of prolonged stressing or for other reasons, the protection specified elsewhere in the specification shall come into effect to prevent damage. C.6.2.5 Dynamic Performance Controls of STATCOM Station The TSP must describe in detail, the dynamic reactive power controls for enhancing stability margin and also damp oscillations of any critical frequencies. The dead band for continuous damping control must be very small so that there are no discernible sustained oscillations. C.6.2.6 Protective Control Functions TSP shall provide all necessary protections including Main and Back-up protections for all protective zones and equipment like transformers, STATCOM Units, MSCs (if applicable), MSRs (if applicable), MV Bus Bar etc. TSP shall provide any protective control functions to meet the performance requirement of STATCOM under the scope of the TSP. a) Overvoltage Protection TSP shall provide adequate overvoltage protection as a result of any normal operation, mal-operation or system event. b) Over current Protection TSP shall provide adequate over-current protection for the STATCOM Station as a result of any abnormal operation, mal-operation or system event. c) Gate level control Supervision TSP shall provide adequate Sub module Gate level control supervision. C.6.2.7 STATCOM Station Response STATCOM station response shall be such that the change in measured system voltage to small disturbance should reach 90% of the desired total change within 30 ms of initiating a 5% step change of voltage reference. The maximum overshoot should not exceed 120% of the total change and the settling time should not exceed 100 ms, after which the voltage should be within ±5% of the final value. This response characteristic within these limits must be respected when the system’s three-phase fault MVA is between the minimum and maximum value defined in clause-5. The response of the system voltage using the actual controller should be validated on a real time simulator during the Factory Acceptance Test (FAT) at the manufacturer’s premises. For the purpose of STATCOM Station, response time measurement and signal conversion of the voltage, the error should not exceed 0.3%. The voltage response acquisition circuit should have a response time of no longer than 10 ms. However, time longer than 10 ms can be allowed provided the requirement of STATCOM response time is met. REC Power Development and Consultancy Limited 186RFP for Selection of Bidder as Transmission Service Provider Figure-4 Response and Settling time C.6.3 Harmonic performance and AC harmonic filter design It is likely that with multi-level VSC based technology, no filters or only a small high- pass filter will be needed. The STATCOM shall be operable without AC filters. The STATCOM Station should be designed to eliminate the effects of any harmonic resonance between its MSRs, MSCs banks, filter branches, and the AC system. To limit the harmonic distortion imposed on the 400 kV transmission system, the additional contribution of harmonic distortion from the STATCOM Station to 400 kV system (PCC) should not exceed 1% for the total and 0.5% for any specific harmonic. C.6.3.1 Filter performance The distortion levels as specified should be met for the following: a) The continuous range of all system and environmental conditions. b) Variation in total filter capacitance due to manufacturing tolerance, ambient temperature, aging, and changes in capacitance up to alarm level. c) Variation in tolerance for STATCOM parameters, such as transformer winding unbalances, valve firing variations MSC and MSR unequal reactor and capacitor reactance between phases. d) System frequency in the range of 48.5 Hz to 50.5 Hz. Calculation should take into account all possible combinations of STATCOMs, MSCs and MSRs. C.6.3.2 Filter component rating The harmonic filter components (and other STATCOM components) should be rated to carry continuously the harmonic currents caused by the background harmonic distortion of the system and the harmonic currents produced by the STATCOM itself. REC Power Development and Consultancy Limited 187RFP for Selection of Bidder as Transmission Service Provider Unless otherwise specified, harmonic currents from the system and the STATCOM of the same order should be added arithmetically. All filter harmonic currents of different order should be added quadratically (root sum of squares). The rated voltage of capacitors should be derived from the largest arithmetic sum of the power-frequency and individual harmonic voltages obtained from stress calculations in continuous operating conditions (Note: Maximum fundamental voltage and maximum harmonic contributions may not exist at the same time for STATCOM configurations including MSRs or MSCs). For filter capacitor voltage rating, the loss of capacitor unit or elements should be considered up to the trip level. The rated voltage of so-called "low voltage" capacitors (e.g. in double or triple tuned filters) should be chosen such as to also withstand imposed transient stresses from faults, energization, or other switching events. C.6.3.3 Harmonic at PCC The STATCOM Station’s contribution to the harmonic distortion levels at the STATCOM Station connection point (PCC) to the transmission system shall not exceed the limits defined in IEEE-2800 standard. C.6.3.4 Harmonic calculation: Chapter 7.3 of CIGRE Publication 139 together with information in PSSE network files given shall be used for the Network harmonic impedance. C.6.4 MV Switchyard • Medium Voltage (MV) delta bus shall be grounded through a Grounding Transformer (i.e. zig-zag winding Transformer) along with a suitable resistor in the neutral. • MV Switchyard of different STATCOM Station branches shall be fenced with a fence height of three (3) meter. To minimize the probability of electrical fault suitable arrangement i.e. electrified fence shall be done to prevent the encroachment of unwanted animals or other to minimize the probability of electrical faults (Ph-E, Ph-Ph). Further bus bar arrangements shall be made in a way to minimize the probability of electrical faults. • Secondary side of the Coupling Transformer shall be provided with suitable surge capacitors to mitigate transfer surges. • For MV bus bar, an Aluminum conductor (Tube, Rectangular Hollow Section or C Section) may be used, however, a suitable bus bar end cover/cap shall be provided to avoid any animal/bird entering the hollow space. REC Power Development and Consultancy Limited 188RFP for Selection of Bidder as Transmission Service Provider C.6.5 Broadband Interference C.6.5.1 Radio Interference The TSP shall take necessary precautions in the form of shielding of valve hall and building or Containers to meet its own requirement together with any requirements that may be specified in Section-Project. Further, the following requirements shall also be met: a) With the STATCOM Station operating at any load upto rated value and within the design range of firing angle, the radio interference level from electromagnetic or electrostatic inductions generated by the STATCOM station shall not exceed 100 micro-volts/m, under fair weather conditions, at 500 m away from STATCOM fence or boundary of the substation whichever is higher. The Radio Interference Level (RIL) criteria shall be achieved at all frequencies within the range of 150 kHz to 300 MHz and with the STATCOM operation at any level up to and including rated value, the design shall provide correcting measures, in case the specified design not being realized in the final installation. In case of any third-party complaints about the radio interference, suitable measures shall be implemented by the TSP. b) Measurements of actual RI at STATCOM Station shall be made by the TSP, at points along the above defined contour and at other critical points. c) RIV (Radio Interference voltage) measured at a phase to ground voltage (266 kV rms) in accordance to NEMA-107 shall not be more than 500 micro-volts for 400 kV system. For other system voltages, IEC/NEMA in the order of preference shall be applicable. C.6.5.2 Interference with Power Line carrier and open wire carrier system The TSP shall take the necessary precautions in the form of noise suppression techniques and filtering devices to prevent harmful interferences from STATCOM Station to the power line carrier communication (PLCC) system operating on connected AC transmission network. The frequency spectra to be protected are: System Frequency spectrum Power Line Carrier 30 kHz to 500 kHz Open Wire Carrier 5 kHz to 30 kHz C.6.6 Audible Noise The TSP shall limit the audible noise in various areas of the STATCOM Station buildings and containers to the following values. Valve hall (Inside) 90 dBA REC Power Development and Consultancy Limited 189RFP for Selection of Bidder as Transmission Service Provider Mechanical equipment areas indoor (measured at 2 meter distance) 75 dBA Mechanical equipment outdoor (Measured at 15 m distance) 75 dBA Control Room Building* 60 dBA At the limits of the STATCOM STATION perimeter fence 80 dBA *This is the background noise from the ventilation system in adjacent rooms, control cubicles etc. Printers, recorders may be switched off during the measurement. C.6.7 Loss Requirements C.6.7.1 The TSP must guarantee the total losses of STATCOM Station, be less than 1% of the reactive power output individually at its inductive limit (STATCOM+MSRs) and capacitive limit (STATCOM+MSCs) for the cumulative highest reactive power output of STATCOM Station at PCC with the worse combination of manufacturing tolerances for the option - 1 to 2 as provided in clause C.3. In case of Option 3 as provided in clause C.3 i.e. +550/-300 MVAr STATCOM without MSC and MSR, the TSP must guarantee the total losses of STATCOM Station will be less than 1.5% of the reactive power output individually at its inductive limit and capacitive limit for the cumulative highest reactive power output of STATCOM Station at PCC with the worse combination of manufacturing tolerances..For the purpose of total loss measurements, it should be assumed that the ambient temperature is 20 °C, the PCC voltage is 1 per unit, and the slope setting is 1%. The STATCOM system may not operate under these conditions, but they provide a common base. C.6.7.2 The total losses shall include all components, as well as different parts or subsystems of the complete STATCOM Station such as coupling transformer, All VSC systems and components, MSC and MSR, Control and protection systems, including ancillary devices such as HMI, fault recorders, and SCADA, Auxiliary Power supply systems, cooling systems, Building ancillary services such as lighting, air conditioning, heating, and ventilation. It may be noted that for the redundant VSC valve levels and dual/redundant control and protection systems, the losses of redundant VSC valve levels and dual control and protection systems shall be considered during loss measurement. C.6.7.3 For the dual or redundant systems design of STATCOM Station, such as dual pumps or redundant fans, dual systems losses are to be excluded, if the dual system is not in service during the normal operation of the STATCOM Station. However, dual systems should be included if they are required to be in service under the defined operating conditions. The same methodology shall be applied for HVAC (heating ventilation and air conditioning systems). C.6.7.4 The TSP is required to prepare documentation for the detailed calculation of total losses based on measurement during Factory Acceptance Tests of major equipment and systems mentioned above as per relevant IS/IEC/IEEE standards and the same shall be preserved and to be submitted to CEA/CTU/GRID-INDIA, as per their requirement. REC Power Development and Consultancy Limited 190RFP for Selection of Bidder as Transmission Service Provider Further for equipment/systems, whose loss measurement cannot be done during Factory Acceptance Test, the same can be measured at the site, and a combination of calculation and measurement shall be used to derive the total losses as specified above. During Loss measurement, all fans, and pumps; valve room and control room air-conditioning system shall be switched on. However, redundant fans, pumps and air-conditioners shall be kept off during loss measurement. C.6.7.5 During the factory tests the losses for the following equipment shall be measured/ assessed as detailed below: Coupling transformer: Losses shall be measured at factory/lab at the maximum rating, at power frequency as per relevant IEC/IS under below mentioned conditions: i. No load loss (Iron loss) at rated voltage and fundamental frequency. ii. Load loss (copper loss) at rating corresponding to maximum continuous current and at 75 °C. iii. Transformer cooling equipment’s loss (Auxiliary loss) at rated voltage and fundamental frequency. Reactors: The losses shall be measured at the factory/lab at the maximum rating at power frequency as per relevant IEC/IS. VSC Valves: Converter losses comprise the losses in power electronic switches [insulated gate bipolar transistor (IGBT) or equivalent], made up of conduction and switching losses, and the losses in DC capacitors, resistors, and inductors used within the converter system. Refer IEEE-1052 for calculating VSC losses. Capacitor: The capacitor losses shall be measured at the manufacturer’s works at power frequency as well as calculated to obtain the losses in the complete bank on the basis of factory measurement. Auxiliary System: Auxiliary. power losses shall be calculated from the kW and efficiency of all motors (name plate rating) of the cooling system, air conditioning, ventilation etc. The higher of the total losses for the entire auxiliary systems occurring at full capacitive capacity MVAr or full Inductive MVAr as the case may be shall be considered for arriving at the total losses. REC Power Development and Consultancy Limited 191RFP for Selection of Bidder as Transmission Service Provider Harmonic Filters, if any: The losses shall be calculated at the maximum STATCOM Station loading at 400 kV and 50 Hz. The calculations shall be on the basis of the tested results of the components. C.6.8 Selection of Insulation Levels C.6.8.1 Arresters: Protective levels of arresters connected to the 400 kV AC Bus Bars of the STATCOM Station shall be coordinated with the insulation and surge arrester Characteristics of the 400 kV AC systems to which the STATCOM Station is to be connected. The specification and characteristics of the surge arresters installed in 400 kV AC system is given in the Substation specifications. The front of wave (FWWL), lightning impulse (LIWL) and switching impulse withstand levels (SIWL) shall be determined by the following margins: a) A SIWL at least 1.15 times the switching impulse protection level. b) A LIWL which is an IEC standard level corresponding to the SIWL and shall be at least 1.25 times the lightning impulse protection level. c) A FWWL which is at least 1.25 times the front of wave protection level. In addition to the above minimum basic requirement, the various insulation level of 400 kV equipment shall be as below. The STATCOM Station equipment, coupling transformers etc. shall be co-ordinated accordingly. Description SIWL LIWL All equipment other than Transformer Bushing and 1050 kVp 1425 kVp winding Transformer Winding 1175 kVp 1425 kVp Transformer Bushing 1175 kVp 1550 kVp C.6.8.2 Valves The requirement of insulation levels of the valves shall be as per the design requirement. C.6.8.3 Air clearances The air clearances shall be determined by the TSP based on the required withstand levels for all waveforms in order to limit the probability of flashover within the STATCOM Station to a target value of one flashover in 15 years. C.6.8.4 Switchyard REC Power Development and Consultancy Limited 192RFP for Selection of Bidder as Transmission Service Provider The air clearances for switchyard equipment shall be equal to or greater than the minimum values as specified in IEC-60071. Altitude correction factor (if any) shall also be considered as per IEC. C.6.8.5 Leakage distances The Creepage/leakage distance across insulation shall be determined by the TSP and shall be adequate to ensure that under conditions of heavy pollution, the probability of a flashover of an insulator does not exceed one in 15 years. However, the leakage distance for all AC insulators for outdoor installation shall not be less than 31 mm/kV of the maximum operating phase to earth rms voltage at the insulator. The leakage distance of equipment connected to 400 kV systems shall not be less than 13020 mm. Specific creepage distance for outdoor bushings, insulator strings and long rod insulators shall be a minimum 31 mm/kV. C.6.9 STATCOM Station availability and reliability The following definitions apply: C.6.9.1 Outage terms: a) Outage The stage in which equipment is unavailable for normal operation due to an event directly related to the equipment which results in a reduction in STATCOM Station capacity. b) Scheduled Outage An outage that can be scheduled at least one week in advance. c) Forced outage The stage in which the equipment is unavailable for normal operation but is not in the scheduled outage stage and which results in a reduction in STATCOM Station capacity i.e. an outage which is not scheduled outage. C.6.9.2 Capacity terms Maximum Continuous Capacity (Pm) The maximum STATCOM Station capacity (MVAr) for which continuous operation under normal conditions is possible. C.6.9.3 Outage duration terms Actual outage duration (AOD) The time elapsed in hours between the start and end of an outage. REC Power Development and Consultancy Limited 193RFP for Selection of Bidder as Transmission Service Provider C.6.9.4 Time Categories a) The number of hours in the reporting period in a full year, the period year is 8760 hours. If the equipment is commissioned, part way through a year, the period hours will be proportionately less than 8760 hours. b) Total Outage hour (TOH) The sum of all outage duration within the reporting period. TOH = AOD C.6.9.5 Availability and Reliability Terms Unavailability: Unavailability is the duration for which the STATCOM Station is not available with a specified rating due to forced outages per year. If part of the station is unavailable, then the unavailability duration shall be counted proportionally. However, if STATCOM is out then its duration shall count as a fully unavailable STATCOM Station. However, If the STATCOM unit is out then the STATCOM Station unavailability shall be counted proportionally to STATCOM capacity. STATCOM Station Control system outage shall count as full STATCOM Station unavailability. ‘OF’ is the Outage Frequency which will be the number of forced outages per year. The period basis for availability and reliability calculations shall be 12 months. The TSP shall ensure that the design will meet the specified guaranteed and design target value of availability and reliability. Outage times for repair, maintenance and replacement of components shall be based on the premise that all items in the list of recommended spare parts are on hand, and that all maintenance schedules of recommended maintenance are adhered to. Reliability calculations shall be made and shall be presented as the expected frequency of unscheduled loss of STATCOM Station capacity. For simultaneous occurrence of events, for either of which a loss of capacity would result, the longer repair time shall be counted. The facilities shall be assumed to be utilized 100% of the time at 100% load, regardless of the actual reactive power generated/absorbed by the STATCOM Station. Hence the availability and reliability assessment will be based on the capability of STATCOM Station to generate/absorb the rated reactive power regardless of whether, it is in service or not. C.6.9.6 Availability Requirement The calculated availability of the system considered on an annual basis shall be equal to or exceed the following target values. REC Power Development and Consultancy Limited 194RFP for Selection of Bidder as Transmission Service Provider Minimum availability requirement of each complete STATCOM Station  Guaranteed for STATCOM Station - 98% The outages of STATCOM Station capacity caused by the failure of equipment outside the scope of the TSP shall not be considered for the calculation of availability and reliability guarantee. However, such outages shall be restricted to 1) Complete loss to 400 kV supply (at PCC) 2) Human Error. Circumstances causing curtailment of STATCOM Station capacity that will be included in reliability and availability assessment and which can lead to forced outages shall include but not be limited to the following: a) Failure of equipment b) Mal-operation of control and protection system c) Failure to start d) Reduction in capacity. C.6.9.7 Reliability Requirement a) Reliability In the assessment of reliability, the following events shall also be considered to constitute a STATCOM Station outage: i) A STATCOM Station shut down. ii) A reduction of STATCOM Station capacity due to an outage of any component of STATCOM Station The calculated reliability of the complete STATCOM Station shall be equal to or exceed the following design target values. The average outage frequency per year for each STATCOM Station shall not exceed the following values: Design target for Max acceptable Guaranteed STATCOM Station value for STATCOM Station Total Number of 3 x Nos. of STATCOM 5 x Nos. of STATCOM Forced Outages Station Station C.6.9.8 GUARANTEED FAILURE RATE OF Sub-modules. (Including all components and electronic). The maximum annual guaranteed failure rate of sub module (including all components and electronic) shall not exceed 1.0% per STATCOM. The failure rate shall not include failures directly attributable to operation and maintenance errors. REC Power Development and Consultancy Limited 195RFP for Selection of Bidder as Transmission Service Provider C.6.9.9 GUARANTEED VALUE OF FAILURE RATE OF AC POWER CAPACITOR The maximum guaranteed annual capacitor failure rate shall not exceed 0.15% except for first unit failure. The capacitor shall be considered as failed if its Capacitance value varies more than ±5% of the (actually measured) name plate value. Leakage of oil from the capacitor and the deformation of the capacitor unit shall be considered as a failure even if the capacitance value is within the tolerance limits. C.7 Design Principles The objective for the design of the STATCOM Station shall be to achieve a high level of availability and reliability as specified. Special attention shall be given to designing the STATCOM Station to avoid forced outages. The TSP shall conduct thorough design reviews to ensure the minimum risk of such outages. The TSP shall give careful attention to related factors affecting STATCOM Station performance such as subsystem and system testing, protective relays co-ordination and proper setting of relays. Except where greater reliability requirements are specified in these specifications, the design basis for STATCOM Station shall be such that no single contingency downstream from the medium voltage bus shall cause a total outage of the STATCOM Station. The following general criteria shall be followed for the design of the control system: a) Use of components similar to those whose reliability has already been proved in use. b) Use of good design practices, surge protection, filtering, and interference buffers to assure immunity to sensitive components and circuits against damage and interference by induced voltages and currents in the external cabling and cubicle wiring. c) Use of fail-safe and self-checking design features. d) Use of component and equipment redundancy, by means of either duplication or triplication with automatic transfer facilities wherever necessary to meet the requirement of these specifications. e) Design which in the event of component failures, provides for transfer to a less complex operating mode. f) Provision of alarm, fault diagnosis and indication C.8 STATCOM Station Main Components C.8.1 STATCOM Unit The main electrical data of the STATCOM Units are the following: REC Power Development and Consultancy Limited 196RFP for Selection of Bidder as Transmission Service Provider o Rated voltage 20 kV Minimum o Rated frequency 50 Hz o Redundancy (Sub Module) 2 Nos. or 5% whichever is higher o Rated Power of each STATCOM unit/Branch 50 MVAr Minimum o Valve Cooling Deionized/Demineralized water In general, the STATCOM units shall equally share the load however under contingency conditions it should be possible to run the units with unequal load. Charging of the DC capacitors of Sub module during the initial start-up shall be achieved by means of Resistors and bypass breaker arrangement. The charging resistor for DC capacitor of the STATCOM Sub module should be designed for three charges per hour followed by the appropriate cooling time. Power for the gate level control shall be derived internally from Sub module. The offered STATCOM Units with their Control system shall be suitably located inside the STATCOM Station Building. C.8.1.1 STATCOM Valve The valve shall be designed to meet the performance requirements described in this specification and as described below. In order to ensure a modern low loss and reliable solution, the STATCOM valve assembly shall use the multi-module (including redundant sub-modules) approach. The valves shall be designed to ensure satisfactory operation according to the overall performance requirements and include all necessary auxiliary equipment required for smooth and reliable operation. The valves shall be indoor air-insulated and cooled by de-mineralized water. The valves shall be of modular design and have removable Sub- Module for ease of maintenance. The valves shall be mounted to allow easy access for visual inspection, routine maintenance and replacement, and facilities shall be provided to enable easy access. C.8.1.2 Semiconductor Switches The electronic switches should be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The valve shall be designed with individual semiconductor switches applied in a conservative manner with regard to their basic design parameters. The semiconductor switch shall meet the requirements of IEC 60747 except where otherwise specified herein. The semiconductor switches shall be designed to withstand all stresses expected under steady state, transient and temporary overvoltage conditions. Basic semiconductor devices shall be of the Press Pack type, or packaged to provide short circuit means in REC Power Development and Consultancy Limited 197RFP for Selection of Bidder as Transmission Service Provider case of device failure such that the STATCOM can continue to operate without interruption. The adjacent sub-module should be protected against the possible explosion of the semiconductor switch. Under the restriction of redundancy (minimum two or 5% whichever is higher) i.e. the failure of any semiconductor switch or sub module or monitoring device etc shall not prevent continued system operation. In the event of any of the above failures, the STATCOM shall annunciate and identify the specific location of the failed device and continue operation until such time as repairs can be scheduled. During such time till the next shutdown can be availed, the STATCOM must continue to operate without downgrading STATCOM capability. Each switching device should be able to operate within component ratings, generally with at least two failed sub-module or levels. The number of possible failed sub- modules or levels as specified shall be consistent with the availability requirements of the STATCOM system. C.8.1.3 Sub module for Multi-Module Topology The key element of the multi-module topology shall be the sub-module. By increasing the number of these sub-modules, it is possible to obtain high voltage with extremely low harmonic distortion and very low dv/dt using a low switching frequency that reduces power losses. Sub-module shall have the following characteristics: VSC sub-modules should be protected against over voltages with appropriate strategies. A description of the failure mode of the switching device and the strategies used for failure should be provided. In each fiber optic cable (having multiple fiber cores) used for control/communication purposes of sub-module at least two fiber cores shall remain available as spare for future use. C.8.1.4 The STATCOM sub-module has DC capacitors that require a charge to allow full functionality and performance. At the startup of the STATCOM Station, the capacitors are discharged. During the energization sequence of the STATCOM, Capacitors are charged from the main power grid via resistor operated in series to the main connection circuits. Once the desired charging voltages are reached, the charging resistor circuit is bypassed using a bypass switch/breaker. The Type and Rating of the charging resistor and associated bypass switch shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station and shall conform to the relevant Standard. C.8.1.5 STATCOM Valve Cooling system REC Power Development and Consultancy Limited 198RFP for Selection of Bidder as Transmission Service Provider A closed-loop recirculating system shall be provided with full heat rejection capacity with redundancy for pumps, heat exchangers, and fans, appropriate to the STATCOM Station availability requirements. The cooling system should be able to maintain full capacity at maximum ambient temperature and maximum STATCOM reactive power output. The cooling system should be able to operate at the lowest ambient temperature and zero output specified. The Valve cooling system shall have black start capability and necessary Uninterruptible Power Supply UPS/ Uninterruptible Motor Drives UMD shall be provided separately for each STATCOM Unit. The valve cooling system shall be designed to meet the performance requirements described in this specification and as described below. a) Each STATCOM Unit shall have its own de-ionized water valve cooling system with redundant pumps. b) For cooling the STATCOM valves, a deionized re-circulating (closed loop) water system shall be used. c) Water to air heat exchanger shall be used for cooling of this de-ionized water. Water to water heat exchanger shall not be employed. d) System shall be designed such that no shut down of STATCOM be resorted to for making up the deionized water in the system. The make-up water should comply with the recommended pH and purity. e) Cooling water shall have a constant flow rate irrespective of loading. The flow rate shall be decided on the basis of extreme operating conditions. f) The control system for the cooling system shall be redundant type including the provision of redundant control supply and main power supply. However, in place of the redundant control system for the cooling system, suitable alternate mode is also acceptable meeting the requirement of fulfilling cooling system operation even if failure of cooling control system. g) 2x100% pumps with one as standby shall be provided for the primary. In case a pump failure occur, the second pump shall automatically switch in without shutting down the STATCOM. An alarm shall be displayed at the control panel for the failure of the first pump and standby pump in operation. h) Each cooling system shall be provided with an independent/dedicated UMD supply however common battery for both UMD power supply may be accepted. An UMD system will provide an extended capability of the STATCOM Station to deliver reactive power without any interruption, adding a buffer against the system faults or during events such as delayed voltage recovery or Transient over Voltage (TOV). i) The secondary cooling system shall be a redundant type such that it shall be possible to take out 10% (minimum one number) of the cooler module (fan unit) of secondary cooling system without affecting the rated performance of STATCOM). REC Power Development and Consultancy Limited 199RFP for Selection of Bidder as Transmission Service Provider j) Normally no make-up water shall be required however in case of expansion vessel level going low; the same shall be replenished automatically by means the of make-up water tank and make up water pump to be supplied with the system. k) TSP shall provide a water treatment plant of sufficient capacity. The purification (treatment) system shall be designed to maintain conductivity below 1 micro Siemens. A resistivity cell in the outgoing water from the deionizer should detect the depletion of ionized material. Filters and deionizers shall be designed to allow replacement during operation. Normal replacement shall not be required more than once every year. l) Filters and deionizer/deoxidizer material shall be designed to allow replacement within minutes without shutdown of the cooling unit. (Normal replacement should not be required more than once/year). m) Primary cooling system shall monitor its own operation and condition of cooling water. n) The protection system of the cooling cycle shall have minimum following alarms: i) Depleted deionizing cell ii) Low water resistivity iii) High water temperature iv) Primary pump stopped v) Fan stopped vi) Primary pump or fan interlock circuits faulty vii) Primary cycle (Make-up water) tank level low viii) Failure of control supply. ix) UMD/UPS fault. o) Following shutdown alarms / TRIP shall be provided with cooling system protection. Excessive low water resistivity excessive high water temperature, complete loss of auxiliary supply to primary pumps, low flow, low pressure etc. p) The dissipative components of the converter are cooled with deionized water. q) The power losses are transferred to the external ambient by means of a deionized water /air heat exchanger. All the piping and other components shall be provided. Complete instrumentation set including following shall be mounted on board in order to check the status of the cooling system:  Conductivity gauge system.  Flow meter equipped with two set points (alarm and trip).  Pressure meter  Two thermometers for the inlet and two thermometers for the outlet (two set points for alarm and trip)  Thermostat REC Power Development and Consultancy Limited 200RFP for Selection of Bidder as Transmission Service Provider r) The status of the cooling system shall be monitored by means of the control system. s) Replacement of certain cooling equipment (e.g. pumps, fans, cooler unit etc.), if defective, shall be possible while the cooling system still operates. C.8.1.6 Tests on STATCOM Unit Valve All applicable tests i.e. Operational Type Tests, Dielectric Type Tests and Test for valve insensitivity to electromagnetic disturbance and Production tests shall be done as per the latest edition of IEC 62927. C.8.2 STATCOM Station Control equipment and operator interface C.8.2.1 Control Equipment The control systems should achieve the functional objectives given in 6.2. The accuracy of voltage should be within ± 1% of the reference voltage. The accuracy of the gradient and linearity of the slope delivered by the STATCOM Station should be defined in relation to the current deviation from the theoretical slope defined in 3.1. The maximum deviation should be less than ± 5% of the nominal current. The control system design shall be based on a single fail criterion i.e. failure of any one component in the system should not result into outage of the complete system. As a minimum, a dual (hot standby) digital programmable controller shall be supplied for each STATCOM unit/branch and STATCOM Station to control the STATCOM, MSRs and MSCs completely including the functions listed as mentioned below: a. The controller shall have diagnostic and self-checking features for both itself and for valves, gate firing and drive circuits, interface hardware, and software. This is required to reduce outage times and to facilitate fault finding. b. The Controller shall be reprogrammable. The Owner shall have at least the following possibility for changing the following reference and limit values via HMI: c. Closed loop Controllers: The STATCOM Station controller shall have the means to modify the reference set points. This refers to the functionality that will allow all the control parameters to be adjustable within selectable limits and is inclusive of, but not limited to following: o Voltage controller o Q controller (reactive power controller). o Supplementary VSC current controller. o Other supplementary control functions. d. Sequence Controllers: The sequence control and open-loop controllers shall include the control of all switchgears and associated control gear and external devices. REC Power Development and Consultancy Limited 201RFP for Selection of Bidder as Transmission Service Provider e. The Controller shall have at least 10% excess I/O capacity to allow future program upgrades to satisfy the changing requirements of the power systems or future extensions to the STATCOM Stations. As a minimum, a control of up to 4 future HV shunt devices (reactors or capacitors) shall be included in the offer. f. All control signals available for remote control must also be available locally so as to ensure that a local operator can operate the STATCOM Station if the communications link between STATCOM Station and remote control centers is lost. g. A changeover switch shall be provided for control of the selection of local or remote control. h. TSP shall provide the equipment necessary for the purpose of control, protection and interlocking of all equipment within the scope of supply. i. TSP shall be responsible for the design and coordination of control, protection and interlocking system and switching sequences within the STATCOM Station. All necessary interfacing required between AC switchyard equipment and STATCOM Station for the above purpose shall also be included in the scope of TSP. j. It is proposed to control STATCOM through a Supervisory Control and Monitoring System (SCADA). All the data shall be acquired through suitable means from the field and various components and control is executed through the redundant HMI. The local STATCOM Station Control system shall consist of a redundant STATCOM Station controller, redundant HMI workstation, Gateway, STATCOM Station Control System Engineering cum Disturbance Recorder (DR), PC which can also be used as standby HMI workstations in case of emergency with associated peripheral equipment such as color laser log Printers, Color laser jet fault record printer, GPS System, Inverter / UPS etc. all interconnected via redundant Ethernet based Station LAN Network. Each work- stations and PCs at STATCOM Station shall have at least 19” LED display. k. In addition to the above, HMI workstation (identical to HMI Workstation provided in the STATCOM Station control room) should also be provided in the control room of the main 400 kV substation. This HMI workstation should be powered from an independent UPS system adequate enough to provide power to the HMI workstation for a minimum two hours in case of auxiliary power failure. l. The control equipment shall satisfy the reliability and availability requirements specified in this specification m. All necessary measures shall be taken to ensure satisfactory operation in the presence of harmonic current and voltage, noise and radio interference signals. The equipment shall be designed to operate in the environmental conditions specified in the specification. n. There should be a provision for independent operation of MSC/MSR after delinking it with STATCOM controls when STATCOM is out of service due to any reason. REC Power Development and Consultancy Limited 202RFP for Selection of Bidder as Transmission Service Provider o. The threshold values for switching the MSC/MSR on/off shall be configurable in all modes of operation. C.8.2.2 Operator Interface a) Each STATCOM Station shall have a SCADA consisting of an HMI which shall provide a Centralized (local) operator control of the STATCOM Station functions. All human interface operations necessary for the control and monitoring of the STATCOM shall be provided at this point. b) Any abnormal condition requiring operator action or intervention or maintenance on any of the STATCOM Station subsystems shall be annunciated at the STATCOM Station control room and the Substation control room. c) The local HMI shall include the following diagrams as different screens in the display system: i. Complete STATCOM Units and STATCOM Station single line diagram including EHV and MV busses ii. AC Auxiliary supply and distribution iii. DC Auxiliary supply and distribution iv. STATCOM Valve cooling systems v. Interlocking system. d) These diagrams shall indicate status, alarms, voltages, currents, etc. The HMI shall provide complete diagnostics on alarm and trip indications as required and discussed in this specification, including SER information. e) A facility shall be provided whereby the local HMI features and functions shall be accessible from remote. A remote user shall be able to view screens and change STATCOM Station parameter settings. f) As the substation where STATCOM Station shall be installed, will be equipped with Sub-station Automation System (SAS) conforming to IEC 61850, it is required that STATCOM Station control and monitoring shall be integrated with SAS at the main Sub-station by the TSP. It is proposed to connect STATCOM Station’s SCADA with SAS through a Gateway and the database, configuration etc of the main substation SAS shall be upgraded to incorporate STATCOM Station events, alarms, Controls (both switchgear and control functions of STATCOM Station like the setting of parameters etc.) so that STATCOM Station can be effectively monitored and controlled from main substation SAS and shall be monitored from Load Dispatch Center (RLDC). C.8.3 STATCOM Station Protection System REC Power Development and Consultancy Limited 203RFP for Selection of Bidder as Transmission Service Provider C.8.3.1 Protection system Design a) To ensure that faults are cleared within stability critical clearing time, to minimize damage to the plant, and to avoid voltage collapse, loss of load, or load limitations, TSP shall provide a high speed main protection scheme. An independent (having a separate measurement system) back-up protection scheme shall be provided in the event of the main protection scheme failing or taken out for maintenance. b) The STATCOM Station shall be completely self-protecting (unit protection). STATCOM Station shall be protected from damage for all conditions of over- current, overvoltage, excessive reactive power loading, unbalance due to loss of capacitor elements, phase-to-phase and phase-to-ground faults, three phase faults, loss of cooling, semiconductor valve or control malfunction, faults (STATCOM, MV system) in individual primary connected components of the STATCOM, HV system faults, etc. The STATCOM Station shall withstand the maximum fault current for a period of the maximum fault clearing time as specified, considering second contingency cases due to the previously mentioned conditions. c) All protection equipment and systems should be properly co-ordinated to prevent incorrect operations of the protection equipment or systems during normal STATCOM Station operation, including anticipated abnormal conditions on the transmission system, as specified. Fail-safe principles should be applied throughout. C.8.3.2 The basic principle and order of precedence for the control and protection shall be, to take care of the following: • Correctly identify a fault, problem or error condition, • Only if necessary, isolate the minimum number of components, subsystems whenever possible, • Utilize degraded modes to the maximum extent possible either directly (no interruption of the STATCOM Station operation) or indirectly (by tripping the STATCOM Station momentarily in order to isolate the branch and re- energization of the STATCOM Station). • Trip STATCOM Station and Block. a) Failure of the STATCOM Station Interface (SCADA interface) shall not result in a Protection trip of the STATCOM Station. A fail-safe philosophy shall be implemented to allow the STATCOM Station to operate safely and independently from the STATCOM Station Interface (SCADA interface). b) Protection equipment shall be designed and applied to provide maximum discrimination between faulty and healthy circuits. REC Power Development and Consultancy Limited 204RFP for Selection of Bidder as Transmission Service Provider c) The Protection shall be sufficiently sensitive to cater to the full range from maximum to minimum fault level conditions. The Protection shall also be suitable for a system fault level equal to the maximum short circuit capacity of the substation. All current transformer designs shall be based on these fault levels. d) All required protective, control devices, etc including auxiliary instrument transformers and panels, relays, cabling, wiring, indication, and all other associated plant and material necessary for the effective operation of the protection systems shall be supplied and installed by TSP. e) The protective relays shall be microprocessor based. Relays shall have approved characteristics and be mounted in dust and moisture-proof cases. The protective relays shall be provided with visual indications for starting, tripping and failure of the protective function. The LEDs shall be reset without opening the covers. The protection relays shall also be equipped with HMI facilities suitable for manual parameter settings and viewing of the settings. Relays with provision for manual operation from outside the case, other than for resetting, are not acceptable. Relay settings shall be visible and readable without having to remove the relay cover. Relays shall be of approved construction and shall be arranged so that adjustments, testing and replacement can be effected with the minimum of time and labor. Auxiliary Relays of the hand reset type, if provided shall be capable of being reset without opening the case. Electrically reset tripping relays shall be provided as necessitated by the system of control, such as for those circuits subject to remote supervisory control. f) Relay contacts shall be suitable for making and breaking the maximum currents which, they may be required to control in normal service but where contacts of the protective relays are unable to deal directly with the tripping currents, approved Auxiliary tripping relays shall be provided. In such cases, the number of auxiliary tripping relays operating in tandem shall be kept to a minimum in order to achieve fast and reliable fault clearance times. Separate contacts shall be provided for alarm and tripping functions. Relay contacts shall make firmly without bounce and the whole of the relay mechanisms shall be as far as possible unaffected by vibration or external magnetic fields g) Steps shall be taken to protect the circuitry from externally impressed transient voltages which could reach the circuitry via connections to instrument transformers or the station battery. The routing of cables should be such as to limit interference to a minimum. Any auxiliary supplies necessary to power solid-state circuits shall be derived from the main station battery and not from batteries internal to the protection. h) Relay communication REC Power Development and Consultancy Limited 205RFP for Selection of Bidder as Transmission Service Provider The Relays shall also have a communication port provided on the front of the relay for configuration and parameter settings as well as downloading of data. A direct port suitable for remote communication shall also be provided at the back of the Relay. This port shall conform to IEC - 61850. i) Tripping schemes  Tripping of MV circuit breakers shall be done by means of two-separated trip signals.  Duplicate high security tripping circuits for MV Circuit Breaker shall comprise two independent high speed (less than 10 ms) high burden (greater than 150 W) tripping relays for each circuit, each with its own independent DC supply. The trip circuits for all circuit breakers need to be equipped with a “lockout” function and it shall be possible for this to be reset manually and remotely by the operator. j) The protection for the power system is based on a normal switching state and an occurrence of a single fault. This means that faults resulting from maintenance as well as the simultaneous occurrence of two or more faults are not taken into account. k) The input circuits of the digital protections shall be monitored by means of a plausibility check. If any incorrect information is found, the protection function shall be blocked by the protection system. All protection relays shall have facilities for monitoring trip circuits. Detection of an interruption in the case of a switched on circuit breaker shall be signaled. l) Test facilities  It shall be possible to test the protective device during operation without causing trips. Links shall be provided for the isolation of individual protection trip circuits and the common protection trip circuit to each circuit breaker trip coil.  Separate test facilities shall be provided for each current and voltage transformer secondary circuit so as to give access for testing of protection relays and associated circuits. The Test facility to be supplied shall have two selectable positions, a Service and a Test position. In the service Position, the test switch connects CTs and VTs signals to the Relays and trip commands to the circuit breaker trip coils. In the Test Position, the test switch applies a short-circuit to the Current Transformer (CT) secondary windings and open circuits the VT secondary cores and allow injection of secondary current and voltage into the relay. At the same time, the Trip commands to the Circuit Breaker Trip Coils are isolated. The test switch supplied shall be to the Approval of the Owner. m) The protection of the electrical system shall be designed and installed in such a way that the failed equipment is disconnected selectively and automatically. REC Power Development and Consultancy Limited 206RFP for Selection of Bidder as Transmission Service Provider All equipment have to remain operative during transient phenomena, which may arise during switching or other disturbances to the system. n) Auxiliary DC Supplies  The protection concept has to be designed in a way so that back-up protection is provided at all times. All protection relays shall be configured in a way that failure of one Auxiliary DC system will not affect the relay. If all DC supplies to the controllers are lost, the STATCOM Station breaker must be tripped via the protection panel. o) Electromagnetic Compatibility  Electronic Relays and other electronic devices and the ancillary circuits connected to them, such as power supplies, current and voltage transformer secondaries, status or tripping or alarm circuits shall be designed to ensure that they are compatible for use in the hostile electrical environment found in an MV or HV substation.  Adequate steps by means of suitable design, shall be taken to prevent Electromagnetic Interference (EMI), (generated by sources such as circuit breakers, disconnectors, lightning, radio or radar emissions, switching contactors in DC circuits etc) or Electrostatic Discharges (ESD) from affecting relay performance or causing damage to components.  All relays offered shall therefore have been type-tested to meet the current requirements of IEC Standards with respect to High Frequency disturbance, Fast Transients, Electrostatic Discharge, Radio Frequency Interference testing etc. p) List of Protection functions for STATCOM Station Coupling Transformer Protection: i) Biased Differential protection (87T) ii) REF protection (64T) iii) Overcurrent protection (50, 51) iv) Ground Overcurrent (51N) v) Over flux protection (HV and MV) vi) Transformer mechanical trips STATCOM MV Bus Protection: i) Bus Differential protection (87) ii) Ground over current protection (51N), used with a neutral Grounding Transformer iii) Under / Over Voltage (59 Ph-Ph) protection iv) Over voltage (Open Delta) protection STATCOM Branch Protection: REC Power Development and Consultancy Limited 207RFP for Selection of Bidder as Transmission Service Provider i) Differential protection (87) ii) Overload protection (49) iii) Overcurrent protection inside delta (50, 51) iv) Negative phase sequence protection (46) v) STATCOM branch overcurrent protection (50, 51, 50N, 51N) MSR Branch Protection: i) Differential protection (87) ii) Ground over current protection (51N) iii) Reactor branch unbalance protection (Negative Phase Sequence) iv) Thermal Overload protection MSC Branch Protection: i) Ground over current protection (51N) ii) Capacitor Overvoltage (Using current signal) protection. iii) Capacitor unbalance protection (60C) iv) Over current protection (50, 51)  The protection functions listed above are the minimum set of function to be provided, any additional protection required to fulfill the requirement of the protection system shall also be provided.  Further protection functions of individual branch (STATCOM, MSC, MSR) shall trip the respective branch MV Circuit Breaker (CB).  All CBs shall be provided with individual Breaker Failure protection relays. Breaker Failure relay shall have the logic based on the current signal or Circuit Breaker close open status.  Any fault on MV bus will trip the 400 kV breaker. However, any branch fault shall be cleared by the respective MV branch Circuit Breaker.  Protection System for the STATCOM valve portion of the STATCOM station shall be provided in the redundant controllers to isolate the STACOM valve during internal overload/overvoltage, ground fault etc. C.8.4 STATCOM Station Fault Recording System An integrated Transient Fault Recording (TFR) System shall be supplied, installed and commissioned. This shall include trigger level settings for analog signal, etc subject to review and comment. Disturbance and event recording facilities are required for local monitoring of the STATCOM following a disturbance on the power system or the STATCOM System. The TFR shall be GPS/NavIC synchronized. The following inputs are required:  All analog signals (output signals) including 3-ph and sequence values of voltage, current.  All digital signals (control outputs, status indications, commands, alarms, and REC Power Development and Consultancy Limited 208RFP for Selection of Bidder as Transmission Service Provider trip indications). Internal STATCOM Station control signals/variables to be selectable.  The accuracy of the TFR for event inputs shall be at least 100 μs (sampling rate of minimum 10 kHz).  The TFR shall have provision for remote access and retrieval of recorded information onto a PC. For this purpose, a communication link to the substation LAN shall be implemented.  The remote software application for data retrieval shall be included.  There shall be multiple channels to view 3-ph and sequence values of voltage, current.  TFR file shall be viewable in any open source software. C.8.5 Mechanically Switched Reactor (MSR) MSR is a fixed source of inductive reactive power connected in shunt to the MV bus of STATCOM Station and switched by means of a circuit breaker (with a control switching device) based on the command from the STATCOM Station control system. The rated capability of MSRs shall be at 400 kV (Referred to as “Point of Common Coupling” or PCC) and in the steady state frequency range of 48.5 Hz-50.5 Hz. However, the MSR Components shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The individual components of MSR shall be able to withstand the onerous conditions imposed by system overvoltage and harmonics. The MSR consists of 3-ph Air Core Reactor, 3-ph MV Circuit breaker (SF6/Vacuum type), associated current transformer, 3-ph Disconnector and associated safety grounding switch. The MSR area shall be fenced and a castle key interlock with safety grounding switch shall be provided for human safety. Specifications for individual components like Air core reactors etc are provided in the subsequent clause. C.8.6 Mechanically switched capacitor (MSC) MSC is a switched 3-phase capacitor bank connected in shunt to the MV bus of STATCOM station and switched automatically by means of a circuit breaker (with control switching device) based on the command from STATCOM Station control system. The rated capability of MSCs shall be at 400 kV (Referred to as “Point of Common Coupling” or PCC) and in the steady state frequency range of 48.5 Hz-50.5 Hz. However, TSP will ensure the corresponding values at PCC (400 kV) for possible operating condition measured at PCC. The MSC Components shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The individual components of MSC shall be able to withstand the onerous conditions imposed by system overvoltages and harmonics. The MSC consists of 3-ph AC power capacitor bank, a current limiting air core reactor as required, 3-ph REC Power Development and Consultancy Limited 209RFP for Selection of Bidder as Transmission Service Provider MV Circuit breaker (SF6/Vacuum type), associated current transformer, 3-ph Disconnector and associated safety grounding switch. The MSC area shall be fenced and a castle key interlock with safety grounding switch shall be provided for human safety. Specifications for individual components like Capacitors, Air core reactors etc are provided in the subsequent clauses. C.8.7 Air Core Reactors a) Reactors shall be air core, dry type, be suitable for outdoor installation and there shall be no tapping on the reactors. The insulation level shall be adequate and TSP has to ensure proper insulation coordination. b) The insulation of the reactor shall be class F and hot spot temperature rise shall not exceed 105 °C above ambient temperature. Winding temperature rise shall not exceed 80 °C above ambient temperature. c) The reactor shall be designed to withstand thermal dynamic shocks and mechanical shocks while in service and during erection. d) The reactor shall fully conform to the relevant IEC standard. e) The reactor shall be designed to withstand overloading due to over voltage as specified and shall also be subjected to excitation by harmonics; the reactor must be able to withstand such events without deterioration in normal life. f) The reactors shall be subjected to type and routine tests in accordance with the latest issue of IEC-60076 as appropriate to the type of reactor provided. g) Tests on Reactors: The reactors shall be subjected to type and routine tests in accordance with the latest issue of IEC-60076 as appropriate to the type of reactor provided. C.8.8 AC POWER CAPACITORS i) General a) The capacitor banks shall comprise capacitor units, discharge devices, protection equipment, series reactor as required, earthing switches, suitably connected in series and parallel, mounted at ground level with protected fencing all around. The number, arrangement and connection of capacitor banks shall be designed to suit the requirement of the compensator as a whole. If convenient, the capacitor banks may be used in conjunction with reactors. In this event, the rating of the capacitor shall be adequate to cope up with the harmonic loading. The frequency variations shall also be considered. To limit the peak inrush current for switching in the capacitors, current limiting reactors with parallel connected damping resistors, if required shall be connected in series with shunt capacitor banks. REC Power Development and Consultancy Limited 210RFP for Selection of Bidder as Transmission Service Provider b) The capacitors shall be provided with internal-type fuses. Alternatively, the fuseless capacitor is also acceptable. c) Fuses shall not melt nor shall deteriorate when subjected to the inrush current during the life of the capacitor bank. d) With the capacitor charged to a peak voltage, the fuses associated with the healthy elements shall not melt when carrying the discharge current resulting from a breakdown of an element or from an external short circuit. e) Fuses shall be capable of disconnecting a faulty element over a range of voltage across the unit terminals from 0.9 Un to 2.0 Un. In addition, if all the elements in the same row of an internally fused capacitor were to fail as a result of a cascading action, the last fuse element to melt shall be capable of successful disconnection with a voltage of not less than 1.5 times. f) After fuse operation the fuse assembly shall be able to withstand continuously at least 1.5 times the rated unit voltage Un across the gap for 10 Seconds. g) Fuses shall preferably be of the current limiting type but fuse system shall in any event be designed to ensure that energy released into a faulty capacitor unit is less than the valve that will cause rupture or bursting of the container. h) The capacitor units shall be the outdoor type. The container of the capacitor shall be of stainless steel. i) Each capacitor unit shall be readily accessible and replaceable without disturbing any other unit. The supporting frames shall be designed to provide adequate ventilation to the units. j) The dielectric fluid used in the capacitor unit shall be environmentally safe and bio- degradable, non-toxic. Polychlorinated Biphenyle (PCB) type dielectric or any of its derivatives shall not be acceptable. ii) Construction and Design Requirement a) The capacitors shall conform to IEC-60871. The capacitors shall be provided with internally mounted discharge resisters with characteristics in accordance with IEC- 60871. b) The current limiting reactors (as required) shall be dry type and connected in series with the capacitor bank. Suitable lifting lugs shall be provided. c) The capacitor enclosure shall have sufficient strength to withstand without damage or loss of life, mechanical load, both in operation and during erection. The loads shall include electromagnetic forces including those during faults external or internal to the capacitor bank, wind loading, forces due to expansion and contraction caused by ambient temperature and load variation, and seismic effects all as specified. REC Power Development and Consultancy Limited 211RFP for Selection of Bidder as Transmission Service Provider d) The capacitor units shall be interchangeable in order to reduce the spare requirements and simplify maintenance procedures. e) The capacitor stack shall be vibration free. The stack shall have a fixed potential, which is connected to one electrical point in the bank. The stack shall be of galvanized structural steel. f) The capacitor racks shall be supplied complete with all capacitor units, insulators, and connections and shall be equipped with lifting lugs/eyes to facilitate assembly into the stacks. The racks shall be constructed of galvanized structural steel. No drilling of galvanized steel shall be allowed. Each rack shall be labeled with the weight of the fully equipped racks, the phase, and the bank of which it forms a part. The maximum and minimum capacitor unit capacitance which may be substituted into the racks as spares shall be suitably identified. Suitable warning labels shall be affixed. g) The capacitor shall be specially designed to be suitable for intermittent duty. h) The capacitors should comply with the overload capacity as per NEMA Standard. i) The capacitor elements shall be vacuum dried inside the case prior to impregnation with dielectric fluid. After impregnation, the capacitor unit shall be sealed immediately upon removal of the impregnated reservoir. j) The discharge resister shall discharge the unit from peak operating voltage to less than 75 Volts within 10 minutes. k) The capacitor case shall be made from type 409 stainless steel or equivalent stainless steel with all joints welded and tested for leaks. l) All racks and bus insulators as well as the insulators used to insulate each stack of capacitor from ground level shall be pincap or post type. The minimum voltage rating shall be 15 kV and low frequency wet withstand voltage of all insulators used to insulate within or between the capacitor rack of a stack shall not be less than three times the actual voltage stress across the insulators. The insulator shall be outdoor type manufactured from wet porcelain. The insulators shall be bolted to the top members of the frame to support electric-grade aluminum buses. m) The size and groupings of the individual capacitor units shall be such that a single blown fuse will not cause the voltage across the parallel group to rise by more than 10%. n) The redundancy to be provided, shall be as per the requirement specified regarding reliability and availability in the clause mentioned elsewhere. iii) Capacitor Unit Failure Detection The stages of capacitor units or element failure detection shall be provided as below: REC Power Development and Consultancy Limited 212RFP for Selection of Bidder as Transmission Service Provider a) A three-step unbalanced current protection shall be provided in each capacitor bank to initially generate an alarm when the unbalance limit is reached and finally to trip the bank in case of the limit is exceeded. b) The first stage shall generate an alarm and the capacitor unit shall continue in service. It may be assumed that the bank shall be disconnected for maintenance within 2 weeks. c) The second stage shall generate a separate alarm and a delayed trip signal which will disconnect the bank after two hours. d) The third stage shall cause immediate disconnection of the Capacitor Bank. iv) Tests on Capacitors All the tests on capacitor units shall be in accordance with the latest issue of IEC 60871. C.8.9 Coupling Transformer The TSP shall provide single phase coupling transformers to operate as 3- phase bank with one unit as a common spare with necessary auxiliary arrangements for stepping down the voltage from 400 kV system to a suitable medium voltage value as required for replacing any one of the faulty phase units without physically shifting the transformer. The Medium Voltage side of the coupling transformer to couple with the STATCOM shall not be less than 20 kV to ensure optimum power transformation. The Coupling Transformer shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The transformer should be designed and rated to carry complete capacitive and inductive reactive loading as specified for STATCOM Station including that of mechanically switched capacitors (MSC) and Reactors (MSR) etc., as well as harmonic currents associated with the most onerous operating conditions of STATCOM Station, without loss of life. The coupling transformer shall be designed in accordance with the most up-to-date experience in STATCOM application and shall incorporate the latest improvements of design currently employed in the industry. The Comprehensive design review of the Coupling Transformer of STATCOM Station shall be carried out by the TSP. C.8.9.1 General Requirements The coupling transformer shall be designed electrically and mechanically for operating conditions peculiar to STATCOM Station operation, which shall include, but not be limited to the following: a) Electrical insulation problems resulting from the transformer being subjected to voltages of distorted sinusoidal wave shape because of saturation, harmonics, trapped charges in capacitors etc. REC Power Development and Consultancy Limited 213RFP for Selection of Bidder as Transmission Service Provider b) The cumulative effect of electro-dynamic forces produced during valve commutation or other short circuit conditions imposed by valve design limitation and valve group operation. c) Harmonic currents due to STATCOM operation, with reference to additional stray losses resulting from these harmonic currents. d) No generation of uncharacteristic harmonics by the transformers. e) Stresses due to normal control operation and other onerous operations such as blocking and de-blocking. f) Stress due to the fast response requirement of STATCOM for loading from 100% inductive to 100% capacitive and vice-versa. g) Overvoltage stresses for which STATCOM shall be designed as per specification would apply to the transformer also. h) All other stresses for which STATCOM Station shall be designed as per specification would apply to the transformer also. i) The transformer and all its accessories like Bushings, CTs etc shall be designed to withstand without damage, the thermal and mechanical effects of any external short circuit to earth and of a short circuit across the terminals of any winding for a period of 3 seconds. The short circuit level of the 400 kV system to which the transformer shall be connected, will be as per the maximum short circuit level of the main substation. Short Circuit level of the Coupling Transformer shall be as per the Short Circuit level of the respective Substation. Short circuit level for HV bushing shall be 63 kA for 1 Sec. j) The transformer shall be capable of being loaded in accordance with IEC 60076 or the overload conditions as specified whichever is the worst. There shall be no limitation imposed by bushings during its terminal fault. k) The transformer shall be capable of withstanding the mechanical stresses caused by symmetrical or asymmetrical faults on any winding. l) The transformer should be designed to carry a certain level of direct current consistent with the STATCOM design. To ensure minimum harmonics generation, the saturation flux density of the transformer should be higher than the maximum flux density reached over the full steady state (continuous operating) range; this margin shall be at least 10%. This maximum flux density (over the full steady-state range) is obtained at the highest secondary voltage during any reactive power generation, highest reference voltage, minimum slope, and minimum continuous frequency. The flux density at the highest secondary voltage shall lie in the linear portion of the BH curve of the core. Any harmonic generated by the transformer should be considered for the design of the STATCOM. m) All protection class Current Transformers in the coupling transformer shall be of PX/PS type. Other details of these Current Transformers shall be as per protection/metering REC Power Development and Consultancy Limited 214RFP for Selection of Bidder as Transmission Service Provider requirements and shall be decided during detailed engineering. However, the parameters of the Winding Temperature Indicator (WTI) of Current Transformer for each winding shall be as per the Coupling Transformer manufacturer. n) Transformers shall be capable of operating under natural cooled conditions up to the specified load. The forced cooling equipment shall come into operation by pre-set contacts of winding temperature indicator and the transformer shall operate as a forced cooling unit initially as Oil Natural Air Forced (ONAF) up to a specified load and then as Oil Forced Air Forced (OFAF). Cooling shall be so designed that during total failure of power supply to cooling fans and oil pumps, the transformer shall be able to operate at full load for at least ten (10) minutes without the calculated winding hot spot temperature exceeding 140 ° (degree) Celsius. Transformers fitted with two coolers, each capable of dissipating 50 percent of the heat due to losses at the continuous maximum rating, shall be capable of operating for 20 minutes in the event of failure of the oil circulating pump or blowers associated with one cooler without the calculated winding hot spot temperature exceeding 140 ° degree Celsius at continuous maximum rating. o) The transformer shall be free from any electrostatic charging tendency (ECT) under all operating conditions when all oil circulation systems are in operation. In general, the oil flow speed shall not exceed 1.0 m/sec within winding in the oil flow system of the transformers. The manufacturer shall ensure that there is no electrostatic charging tendency in the design. The Technical Parameters of the Transformer shall be as below Sl. No. Description Unit Technical Parameters 1.1 Rated Capacity HV MVA To meet the performance MV MVA requirement and ratings of STATCOM. The transformer shall be suitable for 100% reactive loading 1.2 Voltage ratio (Line to Line) 400 / XX (*) 1.3 Single / Three Phase Design Single phase 1.4 Applicable Standard IEC 60076 1.5 Rated Frequency Hz 50 REC Power Development and Consultancy Limited 215RFP for Selection of Bidder as Transmission Service Provider Sl. No. Description Unit Technical Parameters 1.6 Cooling and Percentage Rating ONAN/ONAF/(OFAF or at different coolings ODAF): 60% / 80%/100% OR ONAN/ONAF1/ONAF2: 60% /80%/100% OR OFAF (with 5 x 25% unit cooler if required) 1.7 Impedance at 75 oC (in percentage) HV–MV To suit the design requirements. 1.8 Tolerance on Impedance (HV- % As per IEC MV) 1.9 Service Outdoor 1.10 Duty Continuous Reactive loading 1.11 Overload Capacity IEC-60076-7 1.12 Temperature rise over 50 oC ambient Temp i) Top oil measured by 0C 50 thermometer ii) Average winding measured by 0C 55 resistance Method 1.13 Windings i) System Fault level HV kA 63 MV kA To suit the design requirements. ii) Lightning Impulse withstand Voltage HV kVp 1425 MV kVp * Neutral kVp 170 iii) Switching Impulse withstand Voltage HV kVp 1175 iv) One Minute Power Frequency withstand Voltage HV kVrms 570 MV kVrms * Neutral kVrms 70 v) Neutral Grounding Solidly grounded REC Power Development and Consultancy Limited 216RFP for Selection of Bidder as Transmission Service Provider Sl. No. Description Unit Technical Parameters vi) Insulation HV Graded MV Uniform vii) Tan delta of winding % < 0.5 1.14 Vector Group (3 – ph) YNd* (unless specified differently elsewhere) 1.15 Tap Changer Not Applicable 1.16 Bushing i) Rated voltage HV kV 420 MV kV * Neutral kV 36 ii) Rated current (Min.) HV A * MV A * Neutral A * iii) Lightning Impulse withstand Voltage HV kVp 1550 MV kVp * Neutral kVp 170 iv) Switching Impulse withstand Voltage HV kVp 1175 v) One Minute Power Frequency withstand Voltage HV kVrms 695 MV kVrms * Neutral kVrms 77 vi) Minimum total creepage distances HV mm/kV 31 MV mm/kV 31 Neutral mm/kV 31 vii) Tan delta of bushings HV % Refer Note 2 MV % Refer Note 2 viii) Max Partial discharge level at Um REC Power Development and Consultancy Limited 217RFP for Selection of Bidder as Transmission Service Provider Sl. No. Description Unit Technical Parameters HV pC 10 MV pC 10 Neutral - 1.17 Max Partial discharge level at pC 100 1.58 * Ur /√3 1.18 Max Noise level at rated dB 80 voltage and at principal tap at no load and all cooling Active 1.19 Maximum Permissible Losses of Transformers i) Max. No Load Loss at rated kW To suit the design requirements. voltage and Frequency ii) Max. Load Loss at maximum kW To suit the design requirements. continuous current and at 75O C iii) Max. Auxiliary Loss at rated kW To suit the design requirements. voltage and Frequency Notes: 1. No external or internal Transformers / Reactors are to be used to achieve the specified HV/MV impedances. 2. The criteria for Transformer losses shall be “Copper Loss (Load Loss) > Iron Loss (No Load Loss) > Cooler Loss (Auxiliary Loss)”. 3. (*) marked parameters shall be decided based on STATCOM manufacturer’s requirement. C.8.10 STATCOM Station MV Switchgear The MV Switchgear shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. C.8.10.1 MV Circuit Breaker The MV Circuit Breaker shall comply with the relevant IEC standard and all other relevant Standards, and as specified in this specification. They shall satisfy the General Technical Requirements and shall be designed to operate in the environmental conditions specified in this specification. The Circuit Breaker offered should be of SF6 type/Vacuum type only and of class C2, M2 as per IEC REC Power Development and Consultancy Limited 218RFP for Selection of Bidder as Transmission Service Provider i) The circuit breaker shall be complete with terminal connectors, operating mechanism, control cabinets, piping, interpole cable, cable accessories like glands, terminal blocks, marking ferrules, lugs, pressure gauges, density monitors (with graduated scale), galvanised support structure for CB and control cabinets, their foundation bolts and all other circuit breaker accessories required for carrying out all the functions the CB is required to perform. ii) All necessary parts to provide a complete and operable circuit breaker installation such as main equipment, terminals, control parts, connectors and other devices whether specifically called for herein or not shall be provided. iii) The support structure of the circuit breaker shall be hot dip galvanized. Exposed hardware items shall be hot dip galvanized or Electro-galvanized. iv) MV Circuit Breaker shall be equipped with controlled switching with consequent optimization of switching behavior, when used in:  Switching of Capacitor Bank  Switching of shunt Reactor Bank v) Reactor Switching Duty test shall be conducted on MV Circuit Breaker in line with latest edition of IEC 62271-110. vi) Type Tested for Back-to-Back Capacitor Bank Switching as per latest edition of IEC 62271-100. vii) Routine tests as per IEC: 62271-100 shall be performed on all circuit breakers. viii) The medium voltage circuit breakers in any of the branches shall be designed to switch off metallic three phase short circuits only limited by the transformer impedance of the STATCOM System (Coupling transformer) with the initial short circuit current and DC component according to IEC 60909-0. Thereby the worst case time constant where the maximum short circuit peak and DC component occur shall be considered. The network shall be considered to deliver the maximum short circuit power of the substation. C.8.10.2 MV Isolator and Earth Switch The isolators and earth switches shall comply with the IEC and all other relevant Standards, and as specified in this specification. They shall satisfy the General Technical Requirements and shall be designed to operate in the environmental conditions specified in this specification. i) The isolators and accessories shall conform in general to IEC-62271 series as per relevance (or IS:9921) except to the extent explicitly modified in specification. REC Power Development and Consultancy Limited 219RFP for Selection of Bidder as Transmission Service Provider ii) Earth switches shall be provided on isolators wherever called for. iii) Switches shall be motor operated with local and remote operation features and local manual operation features. Remote operation of Earth Switch is not required. iv) Disconnections and earth switches shall electrically and mechanically be interlocked. Castle Key interlocking facilities shall be provided to mechanically interlock the earth switch and Isolator to the doors of valve rooms. C.8.10.3 Instrument Transformers for STATCOM Station The instrument transformers shall comply with the relevant IEC Standards. They shall satisfy the general Technical Requirement specified in the specification and shall be designed to operate in the environmental conditions specified in this Specification. The instrument transformers provided for control, metering and protective relaying functions shall have voltage and current ratings, accuracy ratings and burden capabilities adequate to provide their designated functions within the overall accuracy requirement of the systems. Voltage Transformers Voltage transformers shall comply with the relevant IEC standards IEC 61869 (Part-1, Part-3 and Part-5). Current Transformers Current transformers shall comply with IEC 61869 (Part-1 and Part-2). Type tests and routine tests as per relevant IEC. C.8.10.4 Surge Arrester TSP shall install the surge arresters necessary for the protection of the equipment associated with the STATCOM Station in accordance with the requirements as per the insulation coordination study. The surge arresters shall give consistent protection to their associated equipment against overvoltage produced by lightning or switching surges, internal or external station faults, and other system disturbances. The surge arresters shall be rated such that they are able to discharge a specified maximum energy due to the application of lightning, switching surges, temporary over voltages and faults as determined by insulation coordination studies, without coming into the temperature region where thermal runaway could result upon subsequent application of maximum transient and steady state voltage conditions. The arrester housing shall be porcelain/composite type. The end fittings shall be made of non-magnetic and corrosion proof material. Internal components shall be designed to eliminate internal corona and also to ensure minimal capacitive coupling with any conducting layer of pollutant on the outside of the porcelain housing. Particular attention shall be given to the high discharge currents REC Power Development and Consultancy Limited 220RFP for Selection of Bidder as Transmission Service Provider which some of the arresters may experience in service due to discharge of stored energy of the AC filter and reactive compensating equipment, tripping of STATCOM etc. C.8.11 STATCOM Station Auxiliary Power Supply The auxiliary supply of STATCOM Station shall conform with the system requirements relating to reliability, availability, and redundancy, performing continuously to help ensure that the complete STATCOM Station operates as per the requirements. STATCOM station Auxiliary supply including all necessary switchgear (viz. AC/DC, lighting boards etc.) shall be completely separate from the main 765/400/220 kV substation auxiliary supply, all loads of STATCOM station shall be fed from this supply. The auxiliary supply provides power to the controllers, cooling system, station supplies, and various other essential and non-essential loads. With the exception of the cooling system, all other essential loads are also connected to the DC system of the STATCOM Station which is also to be provided separately from the DC system of the main 765/400/220 kV substation. The auxiliary supply system shall be able to provide a stable supply for the STATCOM Station during system faults such as single-phase faults, phase-to-phase faults, and three-phase faults and LVRT (Low Voltage Ride Through) to allow continuous operation of the STATCOM Station during these transient events. Auxiliary Supply System of each STATCOM Station shall be fed from two independent sources as per CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007. Additionally, there shall be one emergency incomer from the DG set. Wherever the Voltage variation on the incomer is very high, a solid state AVR (Automatic Voltage Regulator) shall be provided to control the auxiliary supply voltage. All MV incomers shall be provided with suitable CB, disconnector, instrument Transformer etc along with necessary protection system. C.8.12 Fire Protection System for STATCOM Station: Necessary fire protection for STATCOM units, Coupling Transformer, MSC, MCR and Harmonic filter (if any) shall be required. The main features of these protections are as under. Fire Detection and Alarm System: Suitable fire detection system using smoke detectors and/or heat detectors shall be provided in STATCOM Station for all room and areas. These smoke fire detection systems shall be connected to a separate Fire annunciation system clearly identifying the zone. REC Power Development and Consultancy Limited 221RFP for Selection of Bidder as Transmission Service Provider Hydrant System: The hydrant system shall be extended from fire-fighting system of the substation in the yard. Suitable number of hydrants shall be provided for protection of STATCOM Station equipment in the yard namely Coupling Transformer, MSCs, MSRs and Harmonic Filter (if required) etc as applicable for the station. Further suitable number of hydrants shall also be provided for STATCOM Station building HVW System: HVW (High Velocity Water) Spray system shall be provided for coupling transformer. The tapping for HVW system shall be done from nearby transformer/Reactor or any other suitable point of the main substation fire-fighting line. Fire protection system shall be provided in accordance with the Central Electricity Authority (Measures relating to Safety and Electric Supply) Regulations, 2023. C.8.13 Air-conditioning and ventilation system for STATCOM station The STATCOM Station shall be provided with Air conditioning system as per requirement. 1) AC System (Except Valve Hall): Air condition system shall be provided for the following rooms in the STATCOM Building: a. Control and Relay room b. Battery room c. Conference Room d. Store cum workshop e. Cooling system room f. Lobby Capacity and quantity of the AC units shall be decided based on heat load calculation and redundancy requirement. 2) Air-Conditioning System for Valve hall: Air-Conditioning shall be provided for each Valve room for maintaining the following inside conditions round the year: DBT - 35 oC (Maximum) Relative Humidity (RH) - 60% (Maximum) The system shall be designed for an outside ambient temperature of 50 oC. Based on the above system design and parameters for valve room the AC system shall comprise REC Power Development and Consultancy Limited 222RFP for Selection of Bidder as Transmission Service Provider “AHU and Air-cooled DX Condensing units” with one Main and one Standby unit for each room. The system shall be designed for 24 Hours, 365 Days of the year operation to maintain the inside temperatures of the Valve Hall for proper operation of the critical equipment. The air-cooled condensing unit shall be designed for continuous duty. C.9 Engineering studies The TSP shall carry out studies as brought out in this section with a model of the STATCOM in PSSE and PSCAD and documentation of the same shall be preserved and to be submitted to CEA/CTU, as per their requirement. The objective of these studies is to verify the steady state requirement of reactive power under normal and contingent operating conditions for peak and light loads conditions in the network. The studies shall have to be carried out for - Peak Load - Light Load - Contingency Conditions The load flow and dynamic file available with CTU shall be provided to the TSP in PSSE version 34 format. If data is not available typical data shall be assumed by TSP. The studies should demonstrate that the STATCOM system meets all system and equipment specified performance criteria as per the specification. Engineering studies should include, but not be limited to, the studies described in subsequent subsections. C.9.1 System dynamic performance studies Dynamic performance studies should verify that the STATCOM system controls the system’s dynamic performance during system disturbances. Dynamic performance studies include the following: a. Studies verifying that the STATCOM provides adequate dynamic control to meet the system and STATCOM system performance criteria for the system conditions. b. Study of response time and of the STATCOM system’s behavior and contribution to the system’s recovery from faults. c. Studies to verify the operation of any supplementary controls designed to damp power oscillations following system disturbances. d. Studies to evaluate the interaction of the STATCOM controls with the other nearby control systems, including high-voltage direct current (HVDC) controls, generator controls, and controls of other flexible AC transmission systems (FACTS) devices In addition to the above, relevant studies shall include the cases stated as mentioned in Annexure-I C.9.2 Harmonic performance REC Power Development and Consultancy Limited 223RFP for Selection of Bidder as Transmission Service Provider The studies should evaluate resultant maximum harmonic levels at the STATCOM system point of common coupling (PCC), and determine maximum stresses on all STATCOM system components. The study report should include the following: a. Evaluation of specified system and operating conditions (refer to Clause 5) under all possible STATCOM operating conditions. b. Evaluation within maximum ranges of STATCOM system component tolerances (worst performance values may not occur at detuning extremes). c. Evaluation with maximum system voltage unbalance (refers to item 8 and item 9 in Table 3 of Clause 5). d. Evaluation of the worst case resonance condition between STATCOM system and overall system. e. Evaluation of possible resonant over voltages. f. Transformer saturation induced harmonics for component rating calculation only. g. Evaluation of impact considering single phase auto reclose deadtime. C.9.3 Electromagnetic transients, control performance, and overvoltage studies Transient overvoltage studies should be performed with the actual control modeled to verify that the STATCOM system equipment is adequately protected against over voltages and over currents (including excessive valve recovery voltages) from power system transients resulting from switching, fault clearing events, and credible STATCOM system maloperations. Evaluation shall include the following: a. Study of start-up, including transformer energization, shutdown, switching coordination, and other local area network switching events b. Study of STATCOM system protection and protection coordination c. Faults on the high-voltage (HV) and MV bus (single line-to-ground, phase-to- phase, and three-phase) d. Faults across the VSC, capacitors, and other equipment if used. e. Control interaction C.9.4 Insulation coordination study Overall insulation coordination should be verified by considering the results of 8.4 (dynamic over voltages, and fault and switching transients), including the impacts of lightning surges on the STATCOM equipment. This study should determine and verify insulation levels, clearances, and arrester placement and ratings. C.9.5 Other Studies a) Grounding Study REC Power Development and Consultancy Limited 224RFP for Selection of Bidder as Transmission Service Provider b) Protection coordination c) PLC/radio interference d) Magnetic field strength e) Other studies as applicable C.9.6 Software simulation models The TSP shall provide the latest following PSCAD and PSSE simulation model(s) and parameters to CEA/CTU/GRID-INDIA alongwith detailed documentation for the purpose of future simulation to adequately represent and model the proposed STATCOM system in the respective software: a. Stability model. TSP should provide a detailed STATCOM system dynamics model for use in (PSCAD and PSSE) power flow and stability simulation software The model detail should be appropriate and complete for positive-sequence power system simulation and analysis that is typically performed with power flow and transient stability programs. All appropriate control features for such analysis will be modeled, and necessary documentation on the theory and use of model should be provided. Further, a generic model, benchmarked to detailed STATCOM stability model, shall also be furnished for distribution. b. Transient model. TSP should provide a detailed STATCOM transients model for use in PSCAD. The model detail should be appropriate and complete for the transient response calculation of the STATCOM system. All appropriate control features for such analysis will be modeled, and necessary documentation on the theory and use of model should be provided. Further, a generic model, benchmarked to detailed STATCOM transient model, shall also be furnished for distribution. PSS/E files may be used for developing RTDS files/ models. For simulation of STATCOM in PSS/E file (load flow and dynamic) and PSCAD (Transient) model for STATCOM is required for study. TSP will share STATCOM models with CEA, CTU and Grid-India along with detailed documentation for above study purposes and simulations. For PSS/E, both Generic and User-defined models shall be shared by the TSP with the CEA, CTU and Grid-India. Generic model (PSS/E) response shall be benchmarked with user-defined model (PSS/E and PSCAD) to the extent possible by the TSP. Generic models can be shared by the CEA, CTU and Grid-India with the concerned stakeholders/external party(ies) e. g. STUs etc. on need basis. For User Defined model, confidentiality shall be maintained by the CEA, CTU and Grid-India. For PSCAD, User Defined model shall be provided by the TSP for which confidentiality shall be maintained by the CEA, CTU and Grid-India. Both UDM (PSCAD and PSS/E) and Generic model (PSSE) shall be provided by OEMs to CEA/CTU/GRID-INDIA without any NDA (Non-Disclosure Agreement) REC Power Development and Consultancy Limited 225RFP for Selection of Bidder as Transmission Service Provider C.9.7 Factory tests of controls The integrated nature of the performance of the STATCOM in an electrical grid requires the following tests: a. The TSP should perform factory simulator system tests for integrated control and protection system to ensure the proper operation of the same. The control system should be connected to a digital simulator with adequate representation of the electrical network for various conditions. The STATCOM system controller needs to be representative of control functions, including basic controllers but inclusive of supplementary controls, firing controls, and protective functions integrated into the controllers. TSP shall submit the Factory Acceptance Test (FAT) reports of STATCOM controls to CTU/RLDC. b. The simulator should provide an accurate network representation including network harmonic behavior, as well as synchronous condensers, power stations, generators (with AVRs), and pump storage schemes, existing HVDC, SVCs and STATCOMs, future SVCs and STATCOMs, FSC (fixed series capacitors), and shunt reactors/capacitors/filters. STATCOM system control function type tests on a simulator should include the following: - Verification of each control function. - Verification of control linearity. - Verification of control redundancy. - Verification of the monitoring system. - Verification of the protection system with reference to integrated protective functions included in the Controllers and firing controllers. - Verification of overall system performance for minor and major system disturbances. - Verification of processor loading of all digital controllers. - Verification of STATCOM system parallel operation with other controls in the system and control Stability. - Verification of control equipment performance for auxiliary power supply voltage (AC and DC) and frequency variations (AC). - Routine production tests of all control functions, and separately of all protection functions. C.10.0 VISUAL MONITORING SYSTEM FOR WATCH AND WARD OF STATCOM STATION REC Power Development and Consultancy Limited 226RFP for Selection of Bidder as Transmission Service Provider Visual monitoring system (VMS) for effective watch and ward of STACOM station premises covering the areas of entire switchyard, STATCOM building, Coupling Transformer, Cooling Towers and main gate, shall be provided. The TSP shall design, supply, erect, test and commission the complete system including cameras, Digital video recorder system, mounting arrangement for cameras, cables, LAN Switches, UPS and any other items/accessories required to complete the system. Features of VMS system shall be as those specified for main substation. The number of cameras and their locations shall be decided in such a way that any location covered in the area can be scanned. The cameras shall be located in such a way to monitor at least: a) Coupling Transformer, Mechanically Switched Reactors (MSRs) (if any) and Mechanically Switched Capacitors (MSCs) (if any), AC filter banks (if any). b) STATCOM Valve Hall, Cooling System, Electrical and Mechanical Auxiliary area. c) Entrance to STATCOM Station. d) All other Major Equipment (such as CB, CT, VT, SA etc.) The cameras can be mounted on structures, buildings or any other suitable mounting arrangement. C.11.0 Spares, Special Tools and Tackles Considering STATCOM as high technology proprietary equipment of the OEM, the TSP shall ensure necessary spares are procured to maintain the necessary reliability and availability of STATCOM station. Further all necessary special tools and tackles required for erection, testing, commissioning, and maintenance of equipment shall also be taken. REC Power Development and Consultancy Limited 227RFP for Selection of Bidder as Transmission Service Provider Annexure-I Contingency Cases for STATCOM A) N-1 Contingency Contingency at 765 kV level 1. Three Phase Fault close to 765 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Srikakulam 765 kV D/c line (fault persisted for 100 ms) 2. Single Phase to Ground Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping of one circuit of Pendurthi GH – Srikakulam 765 kV D/c line 3. Three Phase Fault close to 765 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Khammam-II 765 kV D/c line (fault persisted for 100 ms) 4. Single Phase to Ground Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit Pendurthi GH – Khammam-II 765 kV D/c line 5. Three Phase Fault close to 765 kV bus of Srikakulam S/s followed by tripping of one circuit of Srikakulam – Angul 765 kV D/c line (fault persisted for 100 ms) 6. Single Phase to Ground Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit of Srikakulam – Angul 765 kV D/c line 7. Three Phase Fault close to 765 kV bus of Srikakulam S/s followed by tripping of one circuit of Srikakulam – Kakinada GH 765 kV D/c line (fault persisted for 100 ms) 8. Single Phase to Ground Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit of Srikakulam – Kakinada GH 765 kV D/c line 9. Three Phase Fault close to 765 kV bus of Khammam-II S/s followed by tripping of one circuit of Khammam-II – Warangal New 765 kV D/c line (fault persisted for 100 ms) 10. Single Phase to Ground Fault close to 765 kV bus of Khammam-II S/s followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit of Khammam-II – Warangal New 765 kV D/c line Contingency at 400 kV level 11. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Maradam 400 kV (Quad) D/c line (fault persisted for 100 ms) 12. Single Phase to Ground Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 REC Power Development and Consultancy Limited 228RFP for Selection of Bidder as Transmission Service Provider second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping of one circuit of Pendurthi GH – Maradam 400 kV (Quad) D/c line 13. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line (fault persisted for 100 ms) 14. Single Phase to Ground Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping of one circuit of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line 15. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of one 765/400kV ICT at Pendurthi GH (fault persisted for 100 ms) 16. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of 1 GW demand at Pendurthi GH (fault persisted for 100 ms) – Load Throwover case B) N-1-1 Contingency Contingency at 765 kV level 17. Case 1 & 2 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Srikakulam 765 kV D/c line) and successful re-closure (dead time 1 second) 18. Case 3 & 4 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Khammam-II 765 kV D/c line) and successful re-closure (dead time 1 second) 19. Case 5 & 6 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Srikakulam – Angul 765 kV D/c line) and successful re-closure (dead time 1 second) 20. Case 7 & 8 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Srikakulam – Kakinada GH 765 kV D/c line) and successful re-closure (dead time 1 second) 21. Case 9 & 10 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Khammam-II S/s followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Khammam-II – Warangal New 765 kV D/c line) and successful re-closure (dead time 1 second) Contingency at 400 kV level 22. Case 11 & 12 (consider as separate cases) + Single Phase Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Maradam 400 kV (Quad) D/c line) and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. 2nd ckt of Pendurthi GH – Maradam 400 kV (Quad) D/c line 23. Case 13 & 14 (consider as separate cases) + Single Phase Fault close to 400 kV bus of REC Power Development and Consultancy Limited 229RFP for Selection of Bidder as Transmission Service Provider Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line) and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. 2nd ckt of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line REC Power Development and Consultancy Limited 230RFP for Selection of Bidder as Transmission Service Provider SPECIFIC TECHNICAL REQUIREMENTS FOR COMMUNICATION The communication requirement shall be in accordance to CEA (Technical Standards for Communication System in Power System Operations) Regulations, 2020, CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations, 2022, CERC (Communication System for inter-State transmission of electricity) Regulations, 2017, CEA (Cyber Security in Power Sector) Guidelines, 2021, CERC Guidelines on “Interface Requirements” 2024 and all above documents as amended from time to time. The communication services viz. SCADA, AGC (wherever applicable), VoIP, AMR and PMU have been identified as critical services and therefore shall be provisioned with 2+2 redundancy i.e. 2 channels for Main Control Centre and 2 channels for Backup Control Centre. In order to meet this requirement, suitable redundancy at port and card level need to be ensured by the TSP to avoid any single point of failure which may lead to interruption in real-time grid operation. PMU to PDC communication (wherever required) shall be through 2 channels to the PDC (main) as there is no backup PDC at present. Accordingly, all the hardware for communication services of station as stated above shall support dual redundancy for data transmission of station to respective main and backup RLDCs The complete ISTS communication system commissioned by TSP under the RFP shall be the asset of ISTS and shall be available for usage of ISTS requirements as suggested by CTU from time to time. In order to meet the requirement for grid management and operation of substations, Transmission Service Provider (TSP) shall provide the following: C.1.0 FOTE Requirement for line bays at Pendurthi (Vizag) S/s (I) TSP shall supply install & commission FODP with minimum 288 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. (II) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum six (6) directions with MSP (Multiplex Section Protection – 1+1). These directions shall exclude protected (1+1) local patching among equipment (if any). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement among Pendurthi (Vizag) S/s, Srikakulam S/s, Khammam-II S/s, Kalpakka S/s and Maradam S/s. The suitable DC Power Supply and backup to be provided for communication equipment. REC Power Development and Consultancy Limited 231RFP for Selection of Bidder as Transmission Service Provider (III) FOTE & FODP Eq can be accommodated in same panel to optimize space. (IV) TSP shall deploy Cyber Security System in compliance with CEA (Cyber Security in Power Sector) Guidelines, 2021 and CEA (Cyber Security in Power Sector) Regulation, from its date of publication/ notification and their amendments thereof. (V) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP. C.2.0 FOTE Requirement for line bays at Srikakulam S/s i) TSP shall supply install & commission FODP with minimum 144 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum three (3) directions with MSP (Multiplex Section Protection – 1+1). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement between Srikakulam S/s and Pendurthi (Vizag) and local patching with control room FOTE. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE/FODP panel shall be installed in the new Bay Kiosk/Switchyard Panel Room (SPR)/Relay panel Room. The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of Srikakulam S/s which shall be communicating with respective control center. TSP to provide necessary FODP sub rack / Splice trays/ Patch cords etc. and optical interfaces/equipment in the existing FOTE/FODP panels in control room for integration with the existing FOTE for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. Alternatively, The TSP may integrate the FOTE under the present scope with existing FOTE in the nearby Kiosk connected to the control room FOTE (if available with spare direction). For this purpose, TSP shall provide necessary FODP sub rack / Splice trays/ Patch cords etc. and suitable optical interfaces/ equipment in the existing FOTE/FODP panels in another Kiosk (SPR). REC Power Development and Consultancy Limited 232RFP for Selection of Bidder as Transmission Service Provider iv) FOTE & FODP Eq can be accommodated in same panel to optimize space. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP. C.3.0 FOTE Requirement for line bays at Warangal New S/s i) TSP shall supply install & commission FODP with minimum 144 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum three (3) directions with MSP (Multiplex Section Protection – 1+1). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement between Khammam-II S/s and Warangal New S/s and local patching with control room FOTE. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE/FODP panel shall be installed in the new Bay Kiosk/Switchyard Panel Room (SPR)/Relay panel Room. The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of Warangal New S/s which shall be communicating with respective control center. TSP to provide necessary FODP sub rack / Splice trays/ Patch cords etc. and optical interfaces/equipment in the existing FOTE/FODP panels in control room for integration with the existing FOTE for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. Alternatively, The TSP may integrate the FOTE under the present scope with existing FOTE in the nearby Kiosk connected to the control room FOTE (if available with spare direction). For this purpose, TSP shall provide necessary FODP sub rack / Splice trays/ Patch cords etc. and suitable optical interfaces/ equipment in the existing FOTE/FODP panels in another Kiosk (SPR). iv) FOTE & FODP Eq can be accommodated in same panel to optimize space. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP REC Power Development and Consultancy Limited 233RFP for Selection of Bidder as Transmission Service Provider C.4.0 FOTE Requirement for line bays at Khammam-II S/s i) TSP shall supply install & commission FODP with minimum 240 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum five (5) directions with MSP (Multiplex Section Protection – 1+1). These directions shall exclude protected (1+1) local patching among equipment (if any). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement among Khammam-II S/s, Pendurthi(Vizag) S/s, Khammam(existing) S/s and Warangal New S/s. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE & FODP Eq can be accommodated in same panel to optimize space. iv) TSP shall deploy Cyber Security System in compliance with CEA (Cyber Security in Power Sector) Guidelines, 2021 and CEA (Cyber Security in Power Sector) Regulation, from its date of publication/ notification and their amendments thereof. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP C.5.0 FOTE Requirement for line bays at Khammam (existing) S/s i) TSP shall supply install & commission FODP with minimum 144 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum three (3) directions with MSP (Multiplex Section Protection – 1+1). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement between Khammam-II S/s and Khammam (existing) S/s and local patching with control room FOTE. The suitable DC Power Supply and backup to be provided for communication equipment. REC Power Development and Consultancy Limited 234RFP for Selection of Bidder as Transmission Service Provider iii) FOTE/FODP panel shall be installed in the new Bay Kiosk/Switchyard Panel Room (SPR)/Relay panel Room. The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of Khammam (existing) S/s which shall be communicating with respective control center. TSP to provide necessary FODP sub rack / Splice trays/ Patch cords etc. and optical interfaces/equipment in the existing FOTE/FODP panels in control room for integration with the existing FOTE for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. Alternatively, The TSP may integrate the FOTE under the present scope with existing FOTE in the nearby Kiosk connected to the control room FOTE (if available with spare direction). For this purpose, TSP shall provide necessary FODP sub rack / Splice trays/ Patch cords etc. and suitable optical interfaces/ equipment in the existing FOTE/FODP panels in another Kiosk (SPR). iv) FOTE & FODP Eq can be accommodated in same panel to optimize space. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP C.6.0 OPGW requirement for LILO of Kalpakka – Maradam 400 kV D/c line at Pendurthi i) On LILO of Kalpakka – Maradam 400 kV D/c line at Pendurthi, TSP shall supply, install & commission OPGW and earthwire as per Tower Configurations: a. Loop-In and Loop out Ckt on Single Towers: Two (2) no. OPGW cable containing 48 Fibres (48F) to be installed & commissioned by the TSP on both the Earthwire peaks. b. Loop-In and Loop out Ckt on Two separate Towers: One (1) no. OPGW cable containing 48 Fibres (48F) on one earthwire peak & conventional earthwire on other E/W peak for both Loop In and Loop Out Lines. ii) The TSP shall install OPGW cables from gantry of Pendurthi (Vizag) station up to the LILO tower with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at Pendurthi (Vizag) station. The LILO portion length is 20 kms (approx.). After LILO, if fiber length for links Pendurthi (Vizag) station to Kalapakka S/s and Pendurthi (Vizag) station to Maradam S/s is above 225 kms then repeater shall be envisaged, otherwise line can be managed as a repeater less link. REC Power Development and Consultancy Limited 235RFP for Selection of Bidder as Transmission Service Provider iii) TSP shall finalize the location of repeater station depending upon the actual site conditions. Further TSP shall comply to the requirements mentioned as per Appendix-F.1 iv) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP Note: Necessary optical interfaces/ FOTE shall be provided by TSP in the FOTE of Kalapakka S/s and Maradam S/s as per link budget requirement due to LILO. C.7.0 Khammam-II – Pendurthi (Vizag) 765 kV D/c line (I) On Khammam-II – Pendurthi (Vizag) 765 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. (II) The TSP shall install this OPGW from gantry of Khammam-II S/s up to the gantry of Pendurthi (Vizag) S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 350 kms (approx.), where repeater may be required to meet the link budget requirement of Khammam-II – Pendurthi (Vizag) link. The same shall be provided by TSP. (III) TSP shall finalize the location of repeater station depending upon the actual site conditions. Further TSP shall comply to the requirements mentioned as per Appendix-F.1 (IV) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. C.8.0 Pendurthi (Vizag) – Srikakulam 765 kV D/c line i) On Pendurthi (Vizag) – Srikakulam 765 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. ii) The TSP shall install this OPGW from gantry of Pendurthi (Vizag) S/s up to the gantry of Srikakulam S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 200 kms (approx.), where repeater may not be required to meet the link budget requirement of Pendurthi (Vizag) – Srikakulam link. iii) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. REC Power Development and Consultancy Limited 236RFP for Selection of Bidder as Transmission Service Provider C.9.0 Khammam-II – Warangal New 765 kV D/c line i) On Khammam-II – Warangal New 765 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. ii) The TSP shall install this OPGW from gantry of Khammam-II S/s up to the gantry of Warangal New S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 100 kms (approx.), where repeater may not be required to meet the link budget requirement of Khammam-II – Warangal New link. iii) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. C.10.0 Khammam-II – Khammam (existing) 400 kV D/c line i) On Khammam-II – Khammam (existing) 400 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. ii) The TSP shall install this OPGW from gantry of Khammam-II S/s up to the gantry of Khammam (existing) S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 20 kms (approx.), where repeater may not be required to meet the link budget requirement of Khammam-II – Khammam (existing) link. iii) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. C.11.0 Specific Requirement for Phasor Measurement Units (PMUs) TSP shall supply, install and commission required No. of Phasor Measurement Units (PMUs) as per the “Guidelines on Unified Philosophy for placement of PMUs in Indian Grid” (along with all amendments if any) issued vide CEA letter No. CEA-PS-14- 12/9/2024-PSETD Division dated 19.03.2025 for the scope of this RFP. The PMUs shall be provided with LAN switch and shall connect with LAN switch of control room of respective substations/ generating stations with Fibre Optic cable. The PMUs shall be connected with the FOTE at Substation/ generating stations for onwards data transmission to the PDC (Phasor Data Concentrator) located at respective RLDC. Configuration work in existing PDC at RLDC for new PMU integration shall be done by respective RLDC, however all the necessary support in this regard shall be ensured REC Power Development and Consultancy Limited 237RFP for Selection of Bidder as Transmission Service Provider by TSP. The maintenance of all the PMUs and associated equipment shall be the responsibility of TSP. Note: Existing Station owner/s to provide necessary support to integrate different equipment and applications of new extended bays with the existing substation e.g. Communication (through FOTE), Voice etc. for smooth operation and monitoring of new added grid elements. C.12.0 Specific Requirement for UNMS Integration of FOTE Communication system integration in UNMS/CSMS TSP is to ensure integration of communication system into UNMS/CSMS as per following: “The new communication equipment/ system under the present scope shall be compatible for integration with existing regional level NMS system/ Centralized Supervision & Monitoring System (CSMS) i.e. Regional UNMS. The local configuration of the new communication equipment/ system at the station end shall be the responsibility of TSP as per followings. The configuration work in the existing centralized NMS/ UNMS at Control center end, for integration of new Communication equipment/ system shall be done by Regional ULDC Team/ NMT, however all the necessary support in this regard shall be ensured by TSP. Requirement for integration of Communication Equipment/ system with Regional UNMS: 1. TSP shall ensure that NMS/EMS/NE supplied by them is NBI compliant and all FCAPS functionality is supported in the NBI such as NE Inventory, Hardware Inventory– Shelf/Slot/Card/SFP/Port, Topology, Protections, Alarms, Performance-real time & periodic, Performance KPI parameters (E-1, STM, Ethernet), Remote Configuration, Cross Connects, Trails & Circuits, Services Provisioning (NE), E-1, STM, Ethernet, TX & RX Trace, loop back and details are published in the NBI guide for the configuration parameters. 2. TSP shall be obliged to provide/share all necessary documentations such as NBI Guide/MIB/IDL/WSDL/API files etc. for onward integration of their NMS/EMS/NE with regional UNMS. 3. The following support shall be provided by TSP for integration of their supplied equipment with regional UNMS: • Enabling & activating NBI license in their EMS/NMS and providing NBI login access along with User credentials REC Power Development and Consultancy Limited 238RFP for Selection of Bidder as Transmission Service Provider • Assist in verifying NBI Connectivity with UNMS vendor for the successful communication and retrieval of data. 4. Assist in troubleshooting (if required) for NBI connectivity along with UNMS vendor for the communication and retrieval of data. For standalone NE which is 5. not integrated with any EMS/NMS, TSP shall provide modality of complete FCAPS data acquisition as above through industry standard programmatic methods and provide the CLI command manual.” Appendix-F.1 Repeater Requirements  If the repeater location is finalized in the Control Room of a nearby substation, TSP shall provide OPGW to accommodate all the fibers in main transmission line on a single Earthwire peak with OPGW Hardware & mid-way Joint Boxes etc. of the line crossing the main line and required approach Cable to accommodate all the OPGW fibers with all associated hardware fittings, to establish connectivity between crossing point of main transmission line up to the repeater equipment in substation control room. TSP shall co-ordinate for Space & DC power supply sharing for repeater equipment. TSP shall provide FODP, FOTE (with STM-16 capacity) with suitable interfaces required for link budget of respective link. OR  If the repeater location is finalized in the nearby substation premises, the TSP shall identify the Space for repeater shelter in consultation with station owner. Further TSP shall provide OPGW to accommodate all the fibers in main transmission line on a single Earthwire peak with OPGW Hardware & mid-way Joint Boxes etc. of the line crossing the main line and required approach Cable/UGFO to accommodate all the OPGW fibers with all associated hardware fittings, to establish connectivity between crossing point of main transmission line up to the substation where the repeater shelter is to be housed. TSP shall provide repeater shelter along with FODP, FOTE (with STM-16 capacity) with suitable interfaces require for link budget of respective link, reliable power supply provisioning for AC and DC supply, battery bank, Air Conditioner and other associated systems. OR  If the repeater location is finalized on land near the transmission tower. TSP shall make the provisions for Land at nearby tower for repeater shelter. Further TSP shall provide required approach Cable to accommodate all the OPGW fibers with all REC Power Development and Consultancy Limited 239RFP for Selection of Bidder as Transmission Service Provider associated hardware fittings to establish connectivity up to the location of repeater shelter. TSP shall provide repeater shelter along with FODP, FOTE (with STM-16 capacity) with suitable interfaces require for link budget of respective link, reliable power supply provisioning for AC and DC supply, battery bank, Air Conditioner and other associated systems Maintenance of OPGW Cable and OPGW Hardware, repeater equipment & items associated with repeater shelter shall be the responsibility of TSP. Figure F.1 REC Power Development and Consultancy Limited 240RFP for Selection of Bidder as Transmission Service Provider C.13.0 PLCC and PABX: Power line carrier communication (PLCC) equipment complete for speech, tele- protection commands and data channels shall be provided on each transmission line. The PLCC equipment shall in brief include the following: - - Coupling device, Coupling filters line traps, carrier terminals, protection couplers, HF cables, PABX (if applicable) and maintenance and testing instruments. - At new substation, a telephone exchange (PABX) of 24 lines shall be provided at as means of effective communication among various buildings of the substation, remote end substations and with control centres (RLDC/ SLDC) etc. - Coupling devices shall be suitable for phase-to-phase coupling for 400 kV Transmission lines. The pass band of coupling devices shall have sufficient margin for adding communication channel in future if required. Necessary protection devices for safety of personnel and low voltage part against power frequency voltages and transient over voltage shall also be provided. - The line traps shall be broad band tuned suitable for blocking the complete range of carrier frequencies. Line Trap shall have necessary protective devices such as lightning arresters for the protection of tuning device. Decoupling network consisting of line traps and coupling capacitors may also be required at certain substation in case of extreme frequency congestion. - The carrier terminals shall be of single side-band (SSB) amplitude modulation (AM) type and shall have 4 kHz band width. PLCC Carrier terminals and Protection couplers shall be considered for both ends of the line. - PLCC equipment for all the transmission lines covered under the scheme shall be provided by TSP. PLCC to be provided for following lines under present scope: Sl. No Line name PLCC configuration 1. Pendurthi (Vizag) – Srikakulam 765 1 set Analog PLCC + 1 set Digital kV D/c line Protection Coupler for each circuit at both ends. 2. Khammam-II – Warangal New 765 1 set Analog PLCC + 1 set Digital kV D/c line Protection Coupler for each circuit at both ends. 3. Khammam-II – Pendurthi (Vizag) 1 set Analog PLCC + 1 set Digital 765 kV D/c line Protection Coupler for each circuit at both ends. REC Power Development and Consultancy Limited 241RFP for Selection of Bidder as Transmission Service Provider 4. Khammam-II – Khammam 1 set Analog PLCC + 1 set Digital (existing) 400 kV D/c line Protection Coupler for each circuit at both ends. - TSP shall provide/ undertake necessary addition/ modification/ shifting/ re- commissioning etc. of PLCC equipment due to LILO of transmission lines: Sl. No Line name PLCC configuration 1. K alpakka – Pendurthi (Vizag) 400 1 set Analog PLCC + 1 set Digital kV D/c line Protection Coupler for each circuit at [formed after LILO] both ends. 2. Pendurthi (Vizag) – Maradam 400kV 1 set Analog PLCC + 1 set Digital D/c line Protection Coupler for each circuit at [formed after LILO] both ends. - Further, CVT and Wave trap for all 765 kV and 400 kV line bays under present scope shall be provided by TSP. - All other associated equipment like cabling, coupling device and HF cable shall also be provided by the TSP. - Two (2) sets of 48 V battery banks for PLCC and communication equipment shall be provided at each new Substation with at least 10-hour battery backup and extended backup, if required. REC Power Development and Consultancy Limited 242RFP for Selection of Bidder as Transmission Service Provider Frequently Asked Queries: 1.0 Transmission Line: 1.1 Please clarify that whether shutdowns for crossing of existing transmission lines of POWERGRID/STUs/ Power Evacuation Lines from Generation Plants/ Any other Transmission Licensee will be given to TSP on chargeable basis or free of cost. Reply: Shutdowns for crossing of existing transmission lines of POWERGRID/ STUs/ Power Evacuation Lines from Generation Plants/ Any other Transmission Licensee will be given to TSP by the concerned owner of the lines as per their own terms and conditions. As far as shutdown of ISTS lines are concerned the same can be availed by approaching respective Regional Power Committee. 1.2 We understand that the suggested swing angle criteria are applicable for Suspension Insulator in Suspension Tower. Further, you are requested to provide similar swing angle and clearance criteria for Pilot Insulator with Jumper and Jumper. Reply: It is clarified that the swing angle criteria (as mentioned in RFP) for transmission lines is applicable for Suspension Insulator in Suspension Tower. Further, as per Clause 3.0 of Specific Technical Requirements for transmission lines, Transmission service Provider (TSP) shall adopt any additional loading/design criteria for ensuring reliability of the line, if so desired and /or deemed necessary. 1.3 We request you to kindly allow that use of diamond configuration at Power line crossings and the existing owner of the lines may be directed to allow the same for the successful bidders. Reply: Power line crossing including Diamond configuration is the responsibility of the TSP. TSP shall formally submit the profile of the crossing section to the owner of the existing line suggesting proposed crossing alternatives. The crossing will have to be carried out as per approval of owner of the existing line. 1.4 It is requested you to kindly provide present status of Forest Clearances if any transmission line corridor area falling in wildlife forest / reserve forest/ mangroves Reply: Based on the preliminary route survey, the process of initiation of forest clearance for the forest stretches, if any, enroute the proposed line alignment will be initiated by way of writing letters to the concerned authority (ies). However, it may be noted that it will be the responsibility of TSP for obtaining forest clearance for the forest stretches as provided in the survey report and also for any forest area encountered during detailed survey. REC Power Development and Consultancy Limited 243RFP for Selection of Bidder as Transmission Service Provider 1.5 For transmission line, no special requirement is specified for type of Insulator and creepage in RFP document. Hence it is understood that bidder can decide the type of insulator along with creepage requirement based on general CEA regulations and relevant standards. Kindly confirm. Reply: The minimum specific creepage distances shall be decided for the site pollution severity in the area of installation keeping in mind further increase in pollution during life of the line. It shall be as per CEA regulations and relevant standards. However, the tower shall be designed considering the porcelain insulators with creepage factor of 31 mm/kV irrespective of type of insulator used. 2.0 Substation 2.1 We understand that space for storage of O&M spare shall be provided by the existing owner within the station boundary without any cost. Kindly confirm. Reply: Space for storage of O&M spares shall be arranged by TSP on its own. 2.2 We presume that the O&M for the end Termination bays will be in the scope of the TSP and TSP shall not be liable for any payment towards O&M to the existing owner of the substation. Kindly confirm. Reply: Operation and maintenance of the bays is solely the responsibility of the TSP. Further, TSP shall follow CEA’s “Operation and Maintenance (O&M) guidelines and Standard Format for Memorandum of Understanding between New TSP and Existing TSP” issued by CEA vide its letter No. I/28514/2023 dated 22.06.2023. 2.3 With reference to subject scheme of existing sub-station, we assumed following scope of work: (a) We assumed internal road is available and need not to be consider in the present scope of work. (b) Drainage is available and need not to consider in the present scope of work. (c) Cable trench extension in adjacent to Main cable trench only under present scope of work. (d) Levelled area being provided by developer for bay extension. Reply: Regarding requirement of internal road, drainage, cable trench, leveling of the bay extension area, bidder is advised to visit site and acquaint themselves with the provisions/facilities available at substation. 2.4 Kindly provide the soil investigation report of soil parameters of existing REC Power Development and Consultancy Limited 244RFP for Selection of Bidder as Transmission Service Provider substation. Reply: Bidder is advised to visit the substation site and ascertain the requisite parameters. 2.5 Kindly confirm, energy accounting of aux. power consumption. Whether it will be on chargeable basis or part of transmission loss. Reply: It will be on a chargeable basis. 2.6 We understand that VMS requirement is for unmanned stations only. For Manned stations VMS is not compulsory. Reply: VMS shall be provided in line with requirements of RfP document. 2.7 It is understood that Construction water and power shall be provided free of cost to TSP by the respective substation owner for construction of new bays. Reply: Arrangement of construction power and water is in the scope of TSP. 2.8 It is understood that the existing fire hydrant system shall be extended by the TSP for bay extension. Reply: Existing fire hydrant system shall be extended from existing system (if required) 2.9 Please clarify the Status of land acquisition for new Substations. Whether the lands have been acquired by BPC and will be transferred to TSP. Reply: The acquisition of land for new substation is in the scope of TSP. 2.10 We understood that no any dedicated metering CT and CVT required for Line/feeders. Further, we understood that requisite Energy meters for various 765 kV, 400 kV and 220 kV Feeders shall be provided and installed by CTU free of cost to TSP. Reply: Dedicated metering CT and CVT are not required for line/feeders. Metering core of existing CT/CVT can be used provided accuracy class matches with metering requirement. Requisite Special Energy Meters shall be provided and installed by CTU at the cost of TSP in C and P panel subject to space availability, else, in separate metering panel (to be provided by TSP at its cost). 2.11 A draft copy of the Connection Agreement may be furnished. A draft copy of the Connection Agreement may be furnished. Reply: Web page link https://www.ctuil.in/formats_gna_transition 2.12 Please clarify whether the spare 765 kV single phase Reactor unit for Bus reactor shall be provided with 1ph 765 kV CB. REC Power Development and Consultancy Limited 245RFP for Selection of Bidder as Transmission Service Provider Reply: As per RfP, the spare 1-Ph reactor unit shall be utilized for all the bus and switchable line reactor banks (including for future reactor banks). Hence, 1ph 765 kV CB shall also be provided with spare 1-Ph reactor for utilizing with bus reactor as well as switchable line reactor. 2.13 It is understood that existing busbar protection has provision for future bays and also PUs are available for future bays. BPC to confirm availability of CU and PU for bays under present scope of work at existing substations. BPC may kindly confirm availability of communication ports for integrating new PUs with the existing CUs at existing substations. Reply: Bus Bar Protection with Central Unit (CU) is required for the new bus section as specified in RfP. Peripheral Units (PUs) shall be provided by the respective bay owner. Further, augmentation/replacement of existing CU, if required, to meet the system requirement shall also be provided for proper functioning of bus bar protection. 2.14 For SCADA, it is understood that necessary process I/O shall be available for future bays and accordingly license for same. BPC to confirm. Reply: Necessary process I/O along with license shall be in the scope of the successful bidder. 2.15 No separate FF system is envisaged under the present scope of work for existing substation. BPC to confirm. Reply: Existing fire-fighting systems shall be extended to meet the additional requirements under present scope. 2.16 PLCC for 220 kV Lines are not under the scope of TSP. BPC to Confirm.It is requested to provide Type of Coupling for 220 kV Transmission Lines under present scope. Reply: PLCC for 220 kV line is in the scope of developer of the line. Inter circuit coupling for 220 kV D/C and phase to phase coupling for 220 kV S/C shall be applicable for PLCC. 2.17 BPC is requested to confirm the availability of space in the existing control rooms at existing substation for execution of extension work under current project. Reply: Switchyard Panel Rooms are generally required for AIS type substation and relay room are required for GIS type substation. Further, if needed, the control room shall be augmented as per requirement. 3.0 Communication 3.1 What are the usage of OPGW, FOTE, PMU etc. under communication requirement of RFP? REC Power Development and Consultancy Limited 246RFP for Selection of Bidder as Transmission Service Provider Reply: User shall be responsible for providing compatible equipment along with appropriate interface for uninterrupted communication with the concerned control center and shall be responsible for successful integration with the communication system provided by CTU. Communication systems e.g. OPGW, FOTE etc. and PMU are required for grid operation through RLDC/SLDC, speech communication, tele-protection and tele- metering. 3.2 Is space for installation of communication panels are provided to TSP in existing Substations incase new bays are in the scope of TSP? Reply: The space related issues are deliberated in the RfP itself. TSP to install FOTE/FODP panels in the new Bay Kiosk (Switchyard Panel Room (SPR)) / Bay Kisok/ Relay Panel Room (in case of GIS S/s). Further, TSP to connect and integrate the proposed FOTE with the existing FOTE in the control room to complete the communication path upto RLDC. In Case 132 kV Substation TSP shall accommodate the said panels either by extension of existing control room or other arrangements. 3.3 How is the OPGW laying done in case of LILO lines? Reply: In case LILO lines are on same towers (e.g. both Line in and Line Out portion are on same towers, generally done LILO of S/C lines). Then 2x48F OPGW shall be required to install by TSP on both earthwire peak on 400 kV and 765 kV lines where two E/W peaks are available. On 220 kV and 132 kV lines where only one E/W peak is available TSP to install one No. 96F OPGW. Incase LILO lines are on different towers (e.g. both Line In and Line Out portion are on different towers, generally done LILO of D/C lines). Then 1x48F OPGW shall be required to install by TSP on one earthwire peak and conventional earthwire on second earthwire peak, on both Line In and Line Out portion towers of 400 kV and 765 kV lines. On 220 kV and 132 kV lines where only one E/W peak is available TSP to install one No. 48F OPGW in place of conventional earthwire. 3.4 How is the OPGW laying done in case Multi circuit Towers? Reply: In case two different lines are using common multi circuit portion for some distance (originating from different stations, may be terminating on same or on different stations). Two No. 48F OPGW to be installed on both E/W peaks for common M/C portion of 765 kV and 400 kV lines. Incase 220/132 kV lines using multi circuit portion where single E/W peak is available one No. 96F may be installed for common multi circuit portion. REC Power Development and Consultancy Limited 247RFP for Selection of Bidder as Transmission Service Provider 3.5 How PMUs are integrated for new bays at existing Substations? Reply: PMU data of new bays to be provided in the ethernet port of switch at control room and thereafter to be connected with existing FOTE of existing substation to send data to PDC of RLDC by TSP. These PMUs shall be provided with GPS/NavIC clock and LAN switch and shall connect with LAN switch of control room of respective substations with Fiber Optic cable. In this regard, the “Guidelines on Unified Philosophy for placement of PMUs in Indian Grid” issued vide letter No. CEA-PS-14-12/9/2024-PSETD Division dated 19.03.2025 shall be followed. 3.6 Is Spare direction available in existing FOTE for integration with new bay kiosk FOTE Reply: The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of substation for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. 3.7 What is the distance from LILO point to proposed substation for feasibility of repeater station? Reply: Tentative Location of LILO point shall be as per survey report of BPC however, exact location to be ascertained after detailed survey by TSP. 3.8 What is the make and model of existing OPGW in case LILO of main line at new substation? Reply: All OPGW(alongwith optical fibers) meet Central Electricity Authority (Technical Standards for Communication System in Power System Operations) Regulations, 2020 and bidder shall install OPGW accordingly. 3.9 In case of LILO of existing line at new substation who shall provide PMUs at existing substation bays? Reply: TSP shall provide the PMUs for the scope under the RfP in compliance of the “Guideline on Unified Philosophy for placement of PMUs in Indian Grid” issued vide letter No. CEA-PS-14-12/9/2024-PSETD Division dated 19.03.2025. 4.0 Planning : 4.1 Whether the Project/ Elements are eligible for early commissioning incentive as per MoP, GoI order dated 15.07.2015. Reply: Commissioning is to be done as per the timeline mentioned in RFP. However, early commissioning shall be treated as per applicable CERC Regulations/orders. REC Power Development and Consultancy Limited 248TRANSMISSION SERVICE AGREEMENT FOR DEVELOPMENT AND OPERATION OF INTER- STATE TRANSMISSION SYSTEM FOR TRANSMISSION OF ELECTRICITY THROUGH TARIFF BASED COMPETITIVE BIDDING FOR TRANSMISSION SYSTEM FOR PROPOSED GREEN HYDROGEN/GREEN AMMONIA PROJECTS IN VIZAG AREA, ANDHRA PRADESH (PHASE -I) BETWEEN THE CENTRAL TRANSMISSION UTILITY OF INDIA LIMITED (NODAL AGENCY) AND [INSERT NAME OF THE SPV] …………Transmission Service Agreement CONTENTS 1 Definitions and Interpretations ............................................................... 5 2 Effectiveness and Term of Agreement ................................................. 18 3 Conditions Subsequent ........................................................................ 20 4 Development of the Project .................................................................. 24 5 Construction of the Project ................................................................... 29 6 Connection and commissioning of the Project ..................................... 34 7 Operation and Maintenance of the Project ........................................... 39 8 Availability of the project ...................................................................... 40 9 Insurances ........................................................................................... 41 10 Billing And Payment of Transmission Charges .................................... 43 11 Force Majeure ...................................................................................... 44 12 Change in Law ..................................................................................... 49 13 Events of Default and Termination ....................................................... 52 14 Liability and Indemnification ................................................................. 57 15 Assignments and Charges ................................................................... 62 16 Governing Law and Dispute Resolution ............................................... 64 17 Representation and Warranties ........................................................... 66 18 Independent Engineer .......................................................................... 68 19 Miscellaneous Provisions ..................................................................... 70 [Insert Name of the SPV] 2 ……2026Transmission Service Agreement THIS TRANSMISISON SERVICE AGREEMENT (hereinafter referred to as “TSA” or “Agreement” or "the Agreement” or “this Agreement") is made on the ………… [Insert day] of…………. [Insert month] of Two Thousand and………… [Insert Year] BETWEEN: The ………………..[Insert name and registered address of Nodal Agency for the project], acting as a Nodal Agency (referred to as the “Nodal Agency”), which expression shall unless repugnant to the context or meaning thereof include its successors, and permitted assigns) as Party of the one part; AND ………………………. [Insert Name of the Transmission Service Provider], incorporated under the Companies Act, 1956/ Companies Act, 2013 (as the case may be), having its registered office at …………………….. (herein after referred to as “Transmission Service Provider” or “TSP” or “ISTS Licensee”, which expression shall unless repugnant to the context or meaning thereof include its successors, and permitted assigns) as Party of the other part; (“Nodal Agency” and “TSP” are individually referred to as “Party” and collectively as the “Parties”) AND WHEREAS: A) In accordance with the Bidding Guidelines, the Bid Process Coordinator (hereinafter referred to as BPC) had initiated a competitive e-reverse bidding process through issue of RFP for selecting a Successful Bidder to build, own, operate and transfer the Project comprising of the Elements mentioned in Schedule 1 (hereinafter referred to as the Project) B) Pursuant to the said e-reverse bidding process, the BPC has identified the Successful Bidder, who will be responsible to set up the Project on build, own, operate and transfer basis to provide Transmission Service in accordance with the terms of this Agreement and the Transmission License. [Insert Name of the SPV] 3 ……2025Transmission Service Agreement C) The Selected Bidder has submitted the Contract Performance Guarantee and acquired one hundred percent (100%) of the equity shareholding of ................................[Insert Name of the SPV], along with all its related assets and liabilities in terms of the provisions of the Share Purchase Agreement. D) The TSP has agreed to make an application for a Transmission License to the Commission for setting up the Project on build, own, operate and transfer basis. E) The TSP has further agreed to make an application to the Commission for the adoption of the Transmission Charges under Section 63 of the Electricity Act, 2003, along with a certification from the Bid Evaluation Committee in accordance with the Bidding Guidelines issued by Ministry of Power, Government of India. F) The TSP has agreed to execute the agreement(s) required, if any, under Sharing Regulations within fifteen (15) days from the date of grant of Transmission License from the Commission. G) The TSP agrees to the terms and conditions laid down under Sharing Regulations, for making available the ISTS and charge the Transmission Charges in accordance with the terms and conditions of Sharing Regulations. H) The billing, collection and disbursement of the Transmission Charges by the CTU to the ISTS Licensee shall be governed as per Sharing Regulations. I) The terms and conditions stipulated in the Transmission License issued by the Commission to the TSP shall be applicable to this Agreement and the TSP agrees to comply with these terms and conditions. In case of inconsistency between the Transmission License terms & conditions and the conditions of this Agreement, the conditions stipulated in the Transmission License granted by the Commission shall prevail. NOW, THEREFORE, IN CONSIDERATION OF THE PREMISES AND MUTUAL AGREEMENTS, COVENANTS AND CONDITIONS SET FORTH HEREIN, IT IS HEREBY AGREED BY AND BETWEEN THE PARTIES HERETO AS FOLLOWS: [Insert Name of the SPV] 4 ……2026Transmission Service Agreement ARTICLE: 1 1 DEFINITIONS AND INTERPRETATIONS 1.1 Definitions: 1.1.1 The words / expressions used in this Agreement, unless as defined below or repugnant to the context, shall have the same meaning as assigned to them by the Electricity Act, 2003 and the rules or regulations framed there under including those issued / framed by the Commission (as defined hereunder), as amended or re-enacted from time to time or the General Clauses Act, failing which it shall bear its ordinary English meaning. The words/expressions when used in this Agreement shall have the respective meanings as specified below: “Acquisition Price” shall have the same meaning as defined in the Share Purchase Agreement; “Act” or "Electricity Act" or “Electricity Act 2003” shall mean the Electricity Act, 2003 and any amendments made to the same or any succeeding enactment thereof; “Affiliate” shall mean a company that either directly or indirectly i. controls or ii. is controlled by or iii. is under common control with a Bidding Company (in the case of a single company) or a Member (in the case of a Consortium) and “control” means ownership by one entity of at least twenty six percent (26%) of the voting rights of the other entity; “Availability” in relation to the Project or in relation to any Element of the Project, for a given period shall mean the time in hours during that period the Project is capable to transmit electricity at its Rated Voltage and shall be expressed in percentage of total hours in the given period and shall be calculated as per the procedure contained in Appendix –IV to Central Electricity Regulatory Commission (Terms and Conditions of Tariff) Regulations, 2024, attached herewith in Schedule 6; “Bid” shall mean technical bid and financial bid submitted by the Bidder, in response to the RFP, in accordance with the terms and conditions of the RFP; “Bid Deadline” shall mean the last date and time for submission of the Bid in response to RFP, as specified in the RFP; [Insert Name of the SPV] 5 ……2026Transmission Service Agreement “Bidding Company” shall refer to such single company that has made a Response to RFP for the Project; “Bidding Consortium / Consortium” shall refer to a group of companies that has collectively made a Response to RFP for the Project; “Bid Documents” or “Bidding Documents” shall mean the RFP, along with all attachments thereto or clarifications thereof; “Bidding Guidelines” shall mean the “Tariff Based Competitive Bidding Guidelines for Transmission Service” and “Guidelines for Encouraging Competition in Development of Transmission Projects” issued by Government of India, Ministry of Power under Section – 63 of the Electricity Act as amended from time to time; “Bid Process Coordinator” or “BPC” shall mean a person or its authorized representative as notified by the Government of India, responsible for carrying out the process for selection of Bidder who will acquire Transmission Service Provider; “Bill” shall mean any bill raised by the CTU on the DICs to recover the Transmission Charges pursuant to the Sharing Regulations; “Business Day” shall mean a day other than Sunday or a statutory holiday, on which the banks remain open for business in the State in which the Nodal Agency’s registered office is located and the concerned TSP are located; “CEA” shall mean the Central Electricity Authority constituted under Section -70 of the Electricity Act; “Change in law” shall have the meaning ascribed thereto in Article 12; “Commercial Operation Date” or “COD” shall mean the date as per Article 6.2; “Commission” or “CERC” shall mean the Central Electricity Regulatory Commission referred to in sub-section (1) of Section 76 of the Electricity Act, 2003 or its successors and assigns; “Competent Court of Law” shall mean the Supreme Court or any High Court, or any tribunal or any similar judicial or quasi-judicial body in India that has jurisdiction to adjudicate upon issues relating to the Project; “Connection Agreement” shall mean the agreement between the CTU or STU or any other concerned parties and the TSP, setting out the terms relating to the connection of the Project to the Inter-connection Facilities [Insert Name of the SPV] 6 ……2026Transmission Service Agreement and use of the Inter State Transmission System as per the provisions of the IEGC, as the case may be; “Consultation Period” shall mean the period of sixty (60) days or such longer period as the Parties may agree, commencing from the date of issue of a TSP’s Preliminary Notice or a Nodal Agency’s Preliminary Termination Notice, as provided in Article 13 of this Agreement, for consultation between the Parties to mitigate the consequence of the relevant event having regard to all the circumstances; “Consents, Clearances and Permits” shall mean all authorizations, licenses, approvals, registrations, permits, waivers, privileges, acknowledgements, agreements, or concessions required to be obtained from or provided by any concerned authority for the development, execution and operation of Project including without any limitation for the construction, ownership, operation and maintenance of the Transmission Lines and/or sub-stations; “Construction Period” shall mean the period from (and including) the Effective Date of the Transmission Service Agreement up to (but not including) the COD of the Element of the Project in relation to an Element and up to (but not including) the COD of the Project in relation to the Project; “Contractors” shall mean the engineering, procurement, construction, operation & maintenance contractors, surveyors, advisors, consultants, designers, suppliers to the TSP and each of their respective sub- contractors (and each of their respective successors and permitted assigns) in their respective capacities as such; “Contract Performance Guarantee” shall mean the irrevocable unconditional bank guarantee, or insurance surety bond or Payment on Order Instrument submitted and to be submitted by the TSP or by the Selected Bidder on behalf of the TSP to the Nodal Agency from a bank mentioned in Annexure 17 of the RFP, in the form attached here to as Schedule 8 (for bank guarantee) or Schedule 8A (for insurance surety bond issued by any of the insurance companies authorized by Insurance Regulatory and Development Authority of India), or Schedule-8B (for Payment on Order Instrument issued by PFC/REC/IREDA, in accordance with Article 3 of this Agreement and which shall include the additional bank guarantee or insurance surety bond or Payment on Order Instrument furnished by the TSP under this Agreement; “Contract Year”, for the purpose of payment of Transmission Charges, shall mean the period beginning on the COD, and ending on the immediately succeeding March 31 and thereafter each period of 12 months [Insert Name of the SPV] 7 ……2026Transmission Service Agreement beginning on April 1 and ending on March 31 provided that the last Contract Year shall end on the last day of the term of the TSA; “CTU” or “Central Transmission Utility” shall have same meaning as defined in the Electricity Act, 2003; “Day” shall mean a day starting at 0000 hours and ending at 2400 hours; “D/C” shall mean Double Circuit; “Designated ISTS Customers” or “DICs” shall have the meaning as ascribed in the Sharing Regulations; “Dispute” shall mean any dispute or difference of any kind between the Parties, in connection with or arising out of this Agreement including any issue on the interpretation and scope of the terms of this Agreement as provided in Article 16; “Effective Date” for the purposes of this Agreement, shall have the same meaning as per Article 2.1 of this Agreement; “Electrical Inspector” shall mean a person appointed as such by the Government under sub-section (1) of Section 162 of the Electricity Act 2003 and also includes Chief Electrical Inspector; “Electricity Rules 2005” shall mean the rules framed pursuant to the Electricity Act 2003 and as amended from time to time; “Element” shall mean each Transmission Line or each circuit of the Transmission Lines (where there are more than one circuit) or each bay of Sub-station or switching station or HVDC terminal or inverter station of the Project, including ICTs, Reactors, SVC, FSC, etc. forming part of the ISTS, which will be owned, operated and maintained by the concerned ISTS Licensee, and which has a separate Scheduled COD as per Schedule 2 of this Agreement and has a separate percentage for recovery of Transmission Charges on achieving COD as per Schedule 5 of this Agreement; “Event of Default” shall mean the events as defined in Article 13 of this Agreement; “Expiry Date” shall be the date which is thirty five (35) years from the COD of the Project; “Financial Closure” shall mean the first Business Day on which funds are made available to the TSP pursuant to the Financing Agreements; [Insert Name of the SPV] 8 ……2026Transmission Service Agreement “Financially Evaluated Entity” shall mean the company which has been evaluated for the satisfaction of the financial requirement set forth in the RFP; “Financing Agreements” shall mean the agreements pursuant to which the TSP is to finance the Project including the loan agreements, security documents, notes, indentures, security agreements, letters of credit and other documents, as may be amended, modified, or replaced from time to time, but without in anyway increasing the liabilities of the Designated ISTS Customers / Nodal Agency; “Financial Year” shall mean a period of twelve months at midnight Indian Standard Time (IST) between 1st April & 31st March; “Force Majeure” and “Force Majeure Event” shall have the meaning assigned thereto in Article 11; “GOI” shall mean Government of India; “Grid Code” / “IEGC” shall mean the Grid Code specified by the Central Commission under Clause (h) of sub-section (1) of Section 79 of the Electricity Act; “Independent Engineer” shall mean an agency/ company, appointed by Nodal Agency in accordance with the Guidelines for Encouraging Competition in Development of Transmission Projects. “Indian Governmental Instrumentality” shall mean Government of India, Government of any State in India or any ministry, department, board, authority, agency, corporation, commission under the direct or indirect control of Government of India or any State Government or both, any political sub-division of any of them including any court or Commission or tribunal or judicial or quasi-judicial body in India but excluding the CTU, TSP and the Designated ISTS Customers; “Insurances” shall mean the insurance cover to be obtained and maintained by the TSP in accordance with Article 9 of this Agreement; “Inter connection Facilities” shall mean the facilities as may be set up for transmission of electricity through the use of the Project, on either one or both side of generating station’s / CTU’s / STU’s / ISTS Licensee’s / Designated ISTS Customer’s substations (as the case may be) which shall include, without limitation, all other transmission lines, gantries, sub- stations and associated equipment not forming part of the Project; “ISTS Licensee” shall be the TSP under this Agreement, consequent to having been awarded a Transmission License by the CERC and shall be [Insert Name of the SPV] 9 ……2026Transmission Service Agreement referred to as the TSP or the ISTS Licensee, as the context may require in this Agreement; “Law” or “Laws” in relation to this Agreement, shall mean all laws including electricity laws in force in India and any statute, ordinance, rule, regulation, notification, order or code, or any interpretation of any of them by an Indian Governmental Instrumentality having force of law and shall include all rules, regulations, decisions and orders of the Commission; “Lead Member of the Bidding Consortium” or “Lead Member” shall mean a company who commits at least 26% equity stake in the Project, meets the technical requirement as specified in the RFP and so designated by other Member(s) in Bidding Consortium; “Lenders” means the banks, financial institutions, multilateral funding agencies, non-banking financial companies registered with the Reserve Bank of India (RBI), insurance companies registered with the Insurance Regulatory & Development Authority (IRDA), pension funds regulated by the Pension Fund Regulatory & Development Authority (PFRDA),mutual funds registered with Securities & Exchange Board of India (SEBI), etc., including their successors and assigns, who have agreed on or before COD of the Project to provide the TSP with the debt financing described in the capital structure schedule, and any successor banks or financial institutions to whom their interests under the Financing Agreements may be transferred or assigned; Provided that, such assignment or transfer shall not relieve the TSP of its obligations to the Nodal Agency under this Agreement in any manner and shall also does not lead to an increase in the liability of the Nodal Agency; “Lenders Representative” shall mean the person notified by the Lender(s) in writing as being the representative of the Lender(s) or the Security Trustee and such person may from time to time be replaced by the Lender(s) pursuant to the Financing Agreements by written notice to the TSP; “Letter of Intent” or “LOI” shall have the same meaning as in the RFP; “Member in a Bidding Consortium / Member” shall mean each company in the Bidding Consortium; “Month” shall mean a period of thirty (30) days from (and excluding) the date of the event; “Monthly Transmission Charges” for any Element of the Project, after COD of the Element till COD of the Project, and for the Project after COD [Insert Name of the SPV] 10 ……2026Transmission Service Agreement of the Project, shall mean the amount of Transmission Charges as specified in Schedule 5 of this Agreement multiplied by no. of days in the relevant month and divided by no. of days in the year; “National Load Despatch Centre” shall mean the centre established as per sub-section (1) of Section 26 of the Electricity Act 2003; “Nodal Agency” shall mean CTU, which shall execute and implement the Transmission Service Agreement (TSA); Provided that while taking major decisions, CTU shall consult CEA on technical matters and any other matter it feels necessary. “Notification” shall mean any notification, issued in the Gazette of India; “Operating Period” for any Element of the Project shall mean the period from (and including) the COD of such Element of the Project, up to (and including) the Expiry Date and for the Project, shall mean the period from (and including) the COD of the Project, up to (and including) the Expiry Date; “Parent Company” shall mean an entity that holds at least twenty six percent (26%) of the paid - up equity capital directly or indirectly in the Bidding Company or in the Member in a Bidding Consortium, as the case may be; "Payment on Order Instrument" shall mean Letter of Undertaking from Indian Renewable Energy Development Agency Limited (IREDA) or Power Finance Corporation Limited (PFC) or REC Limited (REC) [the three non- banking financial institutions under Ministry of New & Renewable Energy (MNRE)/ Ministry of Power (MoP)], to pay in case situation of default of Transmission Service Provider (TSP) in terms of tender conditions/ Power Purchase Agreement (PPA) arises. Such Letter(s) will have same effect as that of a Bank Guarantee issued by any public sector bank. Such "Payment on Order instrument" would have terms and conditions similar to that of any Bank Guarantee given by any public sector bank and would promise to pay the Nodal Agency on demand within stipulated time. TSPs can seek such Letter(s) by offering due security to the above- mentioned three nonbanking financial institutions mentioned above (IREDA, PFC & REC). Nodal Agency shall not accept the instrument of 'Letter of Undertaking' as described above or in any other form, from any other non-banking financial institutions or bank, except IREDA, PFC & REC. [Insert Name of the SPV] 11 ……2026Transmission Service Agreement “Preliminary Termination Notice” shall mean a Nodal Agency’s Preliminary Termination Notice as defined in Article 13 of this Agreement; “Project” shall mean Transmission system for proposed Green Hydrogen /Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)”as detailed in Schedule 1 of this Agreement; “Project Assets” shall mean all physical and other assets relating to and forming part of the Project including: (a) rights over the Site for substations, ROW for transmission lines; (b) tangible & intangible assets such as civil works and equipment including foundations, embankments, pavements, electrical systems, communication systems, relief centres, administrative offices, Sub-stations, software, tower and sub-stations designs etc; (c) project facilities situated on the Site; (d) all rights of the TSP under the project agreements; (e) financial assets, such as receivables, security deposits etc; (f) insurance proceeds; and (g) Applicable Permits and authorisations relating to or in respect of the Transmission System;” “Project Execution Plan” shall mean the plan referred to in Article 3.1.3(c) hereof; “Prudent Utility Practices” shall mean the practices, methods and standards that are generally accepted internationally from time to time by electric transmission utilities for the purpose of ensuring the safe, efficient and economic design, construction, commissioning, operation, repair and maintenance of the Project and which practices, methods and standards shall be adjusted as necessary, to take account of: (i) operation, repair and maintenance guidelines given by the manufacturers to be incorporated in the Project, (ii) the requirements of Law, and (iii) the physical conditions at the Site; (iv) the safety of operating personnel and human beings; [Insert Name of the SPV] 12 ……2026Transmission Service Agreement “Rated Voltage” shall mean voltage at which the Transmission System is designed to operate or such lower voltage at which the line is charged, for the time being, in consultation with the Central Transmission Utility; “Rebate” shall have the meaning as ascribed to in Article 10.3 of this Agreement; “RFP” shall mean Request for Proposal dated 03.02.2026 along with all schedules, annexures and RFP Project Documents attached thereto, issued by the BPC for tariff based competitive bidding process for selection of Bidder as TSP to execute the Project, including any modifications, amendments or alterations thereto; “RFP Project Documents” shall mean the following documents to be entered into in respect of the Project, by the Parties to the respective agreements: a. Transmission Service Agreement, b. Share Purchase Agreement, c. Agreement(s) required under Sharing Regulations and d. Any other agreement as may be required; “RLDC” shall mean the relevant Regional Load Dispatch Centre as defined in the Electricity Act, 2003, in the region(s) in which the Project is located; “RPC” shall mean the relevant Regional Power Committee established by the Government of India for the specific Region(s) in accordance with the Electricity Act, 2003 for facilitating integrated operation of the Power System in that Region; “Scheduled COD” in relation to an Element(s) shall mean the date(s) as mentioned in Schedule 2 as against such Element(s) and in relation to the Project, shall mean the date as mentioned in Schedule 2 as against such Project, subject to the provisions of Article 4.4 of this Agreement, or such date as may be mutually agreed among the Parties; “Scheduled Outage" shall mean the final outage plan as approved by the RPC as per the provisions of the Grid Code; “Selected Bid” shall mean the technical Bid and the Final Offer of the Selected Bidder submitted during e-reverse bidding, which shall be downloaded and attached in Schedule 7 on or prior to the Effective Date; [Insert Name of the SPV] 13 ……2026Transmission Service Agreement “Share Purchase Agreement” shall mean the agreement amongst REC Power Development and Consultancy Limited, ................................[Insert Name of the SPV] and the Successful Bidder for the purchase of one hundred (100%) per cent of the shareholding of the ................................[Insert Name of the SPV] for the Acquisition Price, by the Successful Bidder on the terms and conditions as contained therein; “Sharing Regulations” shall mean the Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020 and as amended from time to time; “Site” in relation to a substation, switching station or HVDC terminal or inverter station, shall mean the land and other places upon which such station / terminal is to be established; “SLDC” shall mean the State Load Despatch Centre established as per sub-section (1) of Section 31 of the Electricity Act 2003; “STU” or “State Transmission Utility” shall be the Board or the Government company, specified as such by the State Government under sub-section (1) of Section 39 of the Electricity Act 2003; “Successful Bidder” or “Selected Bidder” shall mean the Bidder selected pursuant to the RFP and who has to acquire one hundred percent (100%) equity shares of ................................[Insert Name of the SPV], along with all its related assets and liabilities, which will be responsible as the TSP to establish the Project on build, own, operate and transfer basis as per the terms of the TSA and other RFP Project Documents; “TSP’s Preliminary Notice” shall mean a notice issued by the TSP in pursuant to the provisions of Article 13.3 of this Agreement; “Target Availability” shall have the meaning as ascribed hereto in Article 8.2 of this Agreement; “Technically Evaluated Entity” shall mean the company which has been evaluated for the satisfaction of the technical requirement set forth in RFP; “Termination Notice” shall mean a Nodal Agency’s Termination Notice given by the Nodal Agency to the TSP pursuant to the provisions of Articles 3.3.2, 3.3.4, 4.4.2, 5.8, 13.2 and 13.3 of this Agreement for the termination of this Agreement; “Term of Agreement” for the purposes of this Agreement shall have the meaning ascribed thereto in Article 2.2 of this Agreement; [Insert Name of the SPV] 14 ……2026Transmission Service Agreement “Transmission Charges” shall mean the Final Offer of the Selected Bidder during the e-reverse bidding and adopted by the Commission, payable to the TSP as per Sharing Regulations; “Transmission License” shall mean the license granted by the Commission in terms of the relevant regulations for grant of such license issued under the Electricity Act; “Transmission Service” shall mean making the Project available as per the terms and conditions of this Agreement and Sharing Regulations; “Unscheduled Outage” shall mean an interruption resulting in reduction of the Availability of the Element(s) / Project (as the case may be) that is not a result of a Scheduled Outage or a Force Majeure Event. “Ultimate Parent Company” shall mean an entity which owns at least twenty six percent (26%) equity in the Bidding Company or Member of a Consortium, (as the case may be) and in the Technically Evaluated Entity and / or Financially Evaluated Entity (as the case may be) and such Bidding Company or Member of a Consortium, (as the case may be) and the Technically Evaluated Entity and / or Financially Evaluated Entity (as the case may be) shall be under the direct control or indirectly under the common control of such entity; 1.2 Interpretation: Save where the contrary is indicated, any reference in this Agreement to: “Agreement" shall be construed as including a reference to its Schedules, Appendices and Annexures; "Rupee", "Rupees" and “Rs.” shall denote lawful currency of India; “crore” shall mean a reference to ten million (10,000,000) and a “lakh” shall mean a reference to one tenth of a million (1,00,000); "encumbrance" shall be construed as a reference to a mortgage, charge, pledge, lien or other encumbrance securing any obligation of any person or any other type of preferential arrangement (including, without limitation, title transfer and retention arrangements) having a similar effect; "holding company" of a company or corporation shall be construed as a reference to any company or corporation of which the other company or corporation is a subsidiary; "indebtedness" shall be construed so as to include any obligation (whether incurred as principal or surety) for the payment or repayment of money, whether present or future, actual or contingent; [Insert Name of the SPV] 15 ……2026Transmission Service Agreement "person" shall have the meaning as defined in Section 2 (49) of the Act; "subsidiary" of a company or corporation (the holding company) shall be construed as a reference to any company or corporation: (i) which is controlled, directly or indirectly, by the holding company, or (ii) more than half of the issued share capital of which is beneficially owned, directly or indirectly, by the holding company, or (iii) which is a subsidiary of another subsidiary of the holding company, for these purposes, a company or corporation shall be treated as being controlled by another if that other company or corporation is able to direct its affairs and/or to control the composition of its board of directors or equivalent body; "winding-up", "dissolution", "insolvency", or "reorganization" in the context of a company or corporation shall have the same meaning as defined in the Companies Act, 1956/ Companies Act, 2013 (as the case may be). 1.2.1 Words importing the singular shall include the plural and vice versa. 1.2.2 This Agreement itself or any other agreement or document shall be construed as a reference to this or to such other agreement or document as it may have been, or may from time to time be, amended, varied, novated, replaced or supplemented. 1.2.3 A Law shall be construed as a reference to such Law including its amendments or re-enactments from time to time. 1.2.4 A time of day shall, save as otherwise provided in any agreement or document be construed as a reference to Indian Standard Time. 1.2.5 Different parts of this Agreement are to be taken as mutually explanatory and supplementary to each other and if there is any inconsistency between or among the parts of this Agreement, they shall be interpreted in a harmonious manner so as to give effect to each part. 1.2.6 The tables of contents and any headings or sub-headings in this Agreement have been inserted for ease of reference only and shall not affect the interpretation of this Agreement. 1.2.7 All interest payable under this Agreement shall accrue from day to day and be calculated on the basis of a year of three hundred and sixty five (365) days. [Insert Name of the SPV] 16 ……2026Transmission Service Agreement 1.2.8 The words “hereof” or “herein”, if and when used in this Agreement shall mean a reference to this Agreement. 1.2.9 The contents of Schedule 7 shall be referred to for ascertaining accuracy and correctness of the representations made by the Selected Bidder in Article 17.2.1 hereof. [Insert Name of the SPV] 17 ……2026Transmission Service Agreement ARTICLE: 2 2 EFFECTIVENESS AND TERM OF AGREEMENT 2.1 Effective Date: This Agreement shall be effective from later of the dates of the following events: a. The Selected Bidder, on behalf of the TSP, has provided the Contract Performance Guarantee, as per terms of Article 3.1 of this Agreement; and b. The Selected Bidder has acquired for the Acquisition Price, one hundred percent (100%) of the equity shareholding of REC Power Development and Consultancy Limited in ................................[Insert Name of the SPV] along with all its related assets and liabilities as per the provisions of the Share Purchase Agreement. and c. The Agreement is executed and delivered by the Parties; 2.2 Term and Termination: 2.2.1 Subject to Article 2.2.3 and Article 2.4, this Agreement shall continue to be effective in relation to the Project until the Expiry Date, when it shall automatically terminate. 2.2.2 Post the Expiry Date of this Agreement, the TSP shall ensure transfer of Project Assets to CTU or its successors or an agency as decided by the Central Government at zero cost and free from any encumbrance and liability. The transfer shall be completed within 90 days of expiry of this Agreement failing which CTU shall be entitled to take over the Project Assets Suo moto. 2.2.3 This Agreement shall terminate before the Expiry Date in accordance with Article 13 or Article 3.3.2 or Article 3.3.4. 2.3 Conditions prior to the expiry of the Transmission License 2.3.1 In order to continue the Project beyond the expiry of the Transmission License, the TSP shall be obligated to make an application to the Commission at least two (2) years before the date of expiry of the Transmission License, seeking the Commission’s approval for the extension of the term of the Transmission License up to the Expiry Date. [Insert Name of the SPV] 18 ……2026Transmission Service Agreement 2.3.2 The TSP shall timely comply with all the requirements that may be laid down by the Commission for extension of the term of the Transmission License beyond the initial term of twenty-five (25) years & upto the Expiry Date and the TSP shall keep the Nodal Agency fully informed about the progress on its application for extension of the term of the Transmission License. 2.4 Survival: The expiry or termination of this Agreement shall not affect any accrued rights, obligations/ roles and liabilities of the Parties under this Agreement, including the right to receive liquidated damages as per the terms of this Agreement, nor shall it effect the survival of any continuing obligations/ roles for which this Agreement provides, either expressly or by necessary implication, which are to survive after the Expiry Date or termination including those under Articles 3.3.3, 3.3.5, Article 9.3 (Application of Insurance Proceeds), Article 11 (Force Majeure), Article 13 (Events of Default and Termination), Article 14 (Liability & Indemnification), Article 16 (Governing Law & Dispute Resolution), Article 19 (Miscellaneous). 2.5 Applicability of the provisions of this Agreement 2.5.1 For the purpose of Availability, Target Availability and the computation of Availability, Incentive, Penalty, the provisions provided in this Agreement shall apply and any future modifications in the relevant Rules and Regulations shall not be applicable for this Project. 2.5.2 For the purposes of this Agreement for ISTS systems developed under the tariff based competitive bidding framework, the provisions relating to the definitions (Availability and COD), Article 3 (Contract Performance Guarantee and Conditions Subsequent), Article 5 (Construction of the Project), Article 6 (Connection and Commissioning of the Project), Article 8 (Target Availability and calculation of Availability), Article 11 (Force Majeure), Article 12 (Change in Law), Article 13 (Event of Default), Article 14 (Indemnification), Article 15 (Assignment and Charges), Articles 16.1, 16.2 and 16.4 (Governing Laws and Dispute Resolution) and Article 17 (representation and warranties of the ISTS Licensee) of this agreement shall supersede the corresponding provisions under Sharing Regulations. [Insert Name of the SPV] 19 ……2026Transmission Service Agreement ARTICLE: 3 3 CONDITIONS SUBSEQUENT 3.1 Satisfaction of conditions subsequent by the TSP 3.1.1 Within ten (10) days from the date of issue of Letter of Intent, the Selected Bidder, shall: a. Provide the Contract Performance Guarantee, and b. Acquire, for the Acquisition Price, one hundred percent (100%) equity shareholding of ................................[Insert Name of the SPV] from REC Power Development and Consultancy Limited, who shall sell to the Selected Bidder, the equity shareholding of ................................[Insert Name of the SPV], along with all its related assets and liabilities. c. Execute this Agreement; The TSP shall, within five (5) working days from the date of acquisition of SPV by the Selected Bidder, undertake to apply to the Commission for the grant of Transmission License and for the adoption of tariff as required under section-63 of the Electricity Act. The Selected Bidder, on behalf of the TSP, will provide to the Central Transmission Utility of India Limited (being the Nodal Agency) the Contract Performance Guarantee for an amount of Rs. 196.75 Crore (Rupees One Hundred Ninety-Six Crore and Seventy-Five Lakh Only). 3.1.2 The Contract Performance Guarantee shall be initially valid for a period up to three (3) months after the Scheduled COD of the Project and shall be extended from time to time to be valid for a period up to three (3) months after the COD of the Project. In case the validity of the Contract Performance Guarantee is expiring before the validity specified in this Article, the TSP shall, at least thirty (30) days before the expiry of the Contract Performance Guarantee, replace the Contract Performance Guarantee with another Contract Performance Guarantee or extend the validity of the existing Contract Performance Guarantee until the validity period specified in this Article. 3.1.3 The TSP agrees and undertakes to duly perform and complete the following activities within six (6) months from the Effective Date (except for c) below), unless such completion is affected due to any Force Majeure Event, or if any of the activities is specifically waived in writing by the Nodal Agency: [Insert Name of the SPV] 20 ……2026Transmission Service Agreement a. To obtain the Transmission License for the Project from the Commission; b. To obtain the order for adoption of Transmission Charges by the Commission, as required under Section 63 of the Electricity Act 2003; c. To submit to the Nodal Agency, CEA & Independent Engineer, the Project Execution Plan, immediately after award of contract(s) and maximum within one hundred and twenty (120) days from the Effective Date. Also, an approved copy each of Manufacturing Quality Plan (MQP) and Field Quality Plan (FQP) would be submitted to Independent Engineer & Nodal Agency in the same time period. The TSP’s Project Execution Plan should be in conformity with the Scheduled COD as specified in Schedule 2 of this Agreement, and shall bring out clearly the organization structure, time plan and methodology for executing the Project, award of major contracts, designing, engineering, procurement, shipping, construction, testing and commissioning to commercial operation; d. To submit to the Nodal Agency, CEA & Independent Engineer a detailed bar (GANTT) chart of the Project outlining each activity (taking longer than one Month), linkages as well as durations; e. To submit to the Nodal Agency, CEA & Independent Engineer detailed specifications of conductor meeting the functional specifications specified in RFP; f. To achieve Financial Closure; g. To provide an irrevocable letter to the Lenders duly accepting and acknowledging the rights provided to the Lenders under the provisions of Article 15.3 of this Agreement and all other RFP Project Documents; h. To award the Engineering, Procurement and Construction contract (“EPC contract”) for the design and construction of the Project and shall have given to such Contractor an irrevocable notice to proceed; and i. To sign the Agreement(s) required, if any, under Sharing Regulations. 3.2 Recognition of Lenders’ Rights by the Nodal Agency 3.2.1 The Nodal Agency hereby accepts and acknowledges the rights provided to the Lenders as per Article 15.3 of this Agreement and all other RFP Project Documents. 3.3 Consequences of non-fulfilment of conditions subsequent [Insert Name of the SPV] 21 ……2026Transmission Service Agreement 3.3.1 If any of the conditions specified in Article 3.1.3 is not duly fulfilled by the TSP even within three (3) Months after the time specified therein, then on and from the expiry of such period and until the TSP has satisfied all the conditions specified in Article 3.1.3, the TSP shall, on a monthly basis, be liable to furnish to Central Transmission Utility of India Limited (being the Nodal Agency) Additional Contract Performance Guarantee of Rupees Nineteen Crore Sixty-Eight Lakh Only (Rs. 19.68 Crore) within two (2) Business Days of expiry of every such Month. Such additional Contract Performance Guarantee shall be provided to Central Transmission Utility of India Limited (being the Nodal Agency) in the manner provided in Article 3.1.1 and shall become part of the Contract Performance Guarantee and all the provisions of this Agreement shall be construed accordingly. Central Transmission Utility of India Limited (being the Nodal Agency) shall be entitled to hold and / or invoke the Contract Performance Guarantee, including such additional Contract Performance Guarantee, in accordance with the provisions of this Agreement. 3.3.2 Subject to Article 3.3.4, if: (i) the fulfilment of any of the conditions specified in Article 3.1.3 is delayed beyond nine (9) Months from the Effective Date and the TSP fails to furnish additional Contract Performance Guarantee to the Nodal Agency in accordance with Article 3.3.1 hereof; or (ii) the TSP furnishes additional Performance Guarantee to the Nodal Agency in accordance with Article 3.3.1 hereof but fails to fulfil the conditions specified in Article 3.1.3 within a period of twelve (12) months from the Effective Date, the Nodal Agency shall have the right to terminate this Agreement, by giving a Termination Notice to the TSP, in writing, of at least seven (7) days, with a copy to CEA and the Lenders’ Representative in order to enable the Lenders to exercise right of substitution in accordance with Article 15.3 of this Agreement. 3.3.3 If the Nodal Agency elects to terminate this Agreement as per the provisions of Article 3.3.2, the TSP shall be liable to pay to the Nodal Agency an amount of Rs. 196.75 Crore (Rupees One Hundred Ninety-Six Crore and Seventy-Five Lakh Only) as liquidated damages. The Nodal Agency shall be entitled to recover this amount of damages by invoking the Contract Performance Guarantee to the extent of liquidated damages, which shall be required by the Nodal Agency, and the balance shall be returned to TSP, if any. It is clarified for removal of doubt that this Article shall survive the [Insert Name of the SPV] 22 ……2026Transmission Service Agreement termination of this Agreement. 3.3.4 In case of inability of the TSP to fulfil the conditions specified in Article 3.1.3 due to any Force Majeure Event, the time period for fulfilment of the condition subsequent as mentioned in Article 3.1.3, may be extended for a period of such Force Majeure Event. Alternatively, if deemed necessary, this Agreement may be terminated by the Nodal Agency by giving a Termination Notice to the TSP, in writing, of at least seven (7) days, with a copy to CEA and the Lenders’ Representative in order to enable the Lenders to exercise right of substitution in accordance with Article 15.3 of this Agreement and the Contract Performance Guarantee shall be returned as per the provisions of Article 6.5.1. Provided, that due to the provisions of this Article 3.3.4, any increase in the time period for completion of conditions subsequent mentioned under Article 3.1.3, shall lead to an equal increase in the time period for the Scheduled COD. If the Scheduled COD is extended beyond a period of one hundred eighty (180) days due to the provisions of this Article 3.3.4, the TSP will be allowed to recover the interest cost during construction corresponding to the period exceeding one hundred eighty (180) days by adjustment in the Transmission Charges in accordance with Schedule 9. 3.3.5 Upon termination of this Agreement as per Articles 3.3.2 and 3.3.4, the Nodal Agency may take steps to bid out the Project again. 3.3.6 The Nodal agency, on the failure of the TSP to fulfil its obligations, if it considers that there are sufficient grounds for so doing, apart from invoking the Contract Performance Guarantee under para 3.3.3 may also initiate proceedings for blacklisting the TSP as per provisions of Article 13.2 of TSA. 3.4 Progress Reports The TSP shall notify the Nodal Agency and CEA in writing at least once a Month on the progress made in satisfying the conditions subsequent in Articles 3.1.3. [Insert Name of the SPV] 23 ……2026Transmission Service Agreement ARTICLE: 4 4 DEVELOPMENT OF THE PROJECT 4.1 TSP's obligations in development of the Project: Subject to the terms and conditions of this Agreement, the TSP at its own cost and expense shall observe, comply with, perform, undertake and be responsible: a. for procuring and maintaining in full force and effect all Consents, Clearances and Permits, required in accordance with Law for development of the Project; b. for financing, constructing, owning and commissioning each of the Element of the Project for the scope of work set out in Schedule 1 of this Agreement in accordance with: i. the Electricity Act and the Rules made thereof; ii. the Grid Code; iii. the CEA Regulations applicable, and as amended from time to time, for Transmission Lines and sub-stations:  the Central Electricity Authority (Technical Standards for Connectivity to the Grid) Regulations, 2007;  Central Electricity Authority (Technical Standards for construction of Electrical Plants and Electric Lines) Regulation, 2010;  Central Electricity Authority (Grid Standard) Regulations, 2010;  Central Electricity Authority (Safety requirements for construction, operation and maintenance of Electrical Plants and Electrical Lines) Regulation, 2011;  Central Electricity Authority (Measures relating to Safety and Electricity Supply) Regulation, 2010;  Central Electricity Authority (Technical Standards for Communication System in Power System Operation) Regulations, 2020. [Insert Name of the SPV] 24 ……2026Transmission Service Agreement iv. Safety/ security Guidelines laid down by the Government; v. Prudent Utility Practices, relevant Indian Standards and the Law; not later than the Scheduled COD as per Schedule 2 of this Agreement; c. for entering into a Connection Agreement with the concerned parties in accordance with the Grid Code. d. for owning the Project throughout the term of this Agreement free and clear of any encumbrances except those expressly permitted under Article 15 of this Agreement; e. to co-ordinate and liaise with concerned agencies and provide on a timely basis relevant information with regard to the specifications of the Project that may be required for interconnecting the Project with the Interconnection Facilities; f. for providing all assistance to the Arbitrators as they may require for the performance of their duties and responsibilities; g. to provide to the Nodal Agency and CEA, on a monthly basis, progress reports with regard to the Project and its execution (in accordance with prescribed form) to enable the CEA to monitor and co-ordinate the development of the Project matching with the Interconnection Facilities; h. to comply with Ministry of Power order no. 25-11/6/2018 – PG dated 02.07.2020 as well as other Guidelines issued by Govt. of India pertaining to this; i. to procure the products associated with the Transmission System as per provisions of Public Procurement (Preference to Make in India) orders issued by Ministry of Power vide orders No. A-1/2021- FSC- Part(5) dated 16.11.2021 and No.: P45021/2/2017-PP (BE-II)-Part-4 Vol.II dated 19.07.2024 issued by Ministry of Power for transmission sector, as amended from time to time read with Department for Promotion of Industry and Internal Trade (DPIIT) orders in this regard (Procuring Entity as defined in above orders shall deemed to have included Selected Bidder and/ or TSP). Also, to comply with Department of Expenditure, Ministry of Finance vide Order (Public Procurement No 1) bearing File No. [Insert Name of the SPV] 25 ……2026Transmission Service Agreement 6/18/2019-PPD dated 23.07.2020, Order (Public Procurement No 2) bearing File No. 6/18/2019-PPD dated 23.07.2020 and Order (Public Procurement No. 3) bearing File No. 6/18/2019- PPD, dated 24.07.2020, Office Memorandum (OM) No. F.18/37/2020-PPD dated 08.02.2021, OM No. F.12/1/2021- PPD(Pt.) dated 02.03.2021, OM No. F.7/10/2021-PPD dated 08.06.2021 and Order (Public Procurement No 4) bearing File No. F.7/10/2021- PPD dated 23.02.2023, as amended from time to time, regarding public procurement from a bidder of a country, which shares land border with India; j. to submit to Nodal Agency information in the prescribed format [To be devised by Nodal Agency] for ensuring compliance to Article 4.1 i) above. k. to comply with all its obligations undertaken in this Agreement. 4.2 Roles of the Nodal Agency in implementation of the Project: 4.2.1 Subject to the terms and conditions of this Agreement, the Nodal Agency shall be the holder and administrator of this Agreement and shall inter alia: a. appoint an Independent Engineer within 90 days of the Effective Date b. provide letters of recommendation to the concerned Indian Governmental Instrumentality, as may be requested by the TSP from time to time, for obtaining the Consents, Clearances and Permits required for the Project; c. coordinate among TSP and upstream/downstream entities in respect of Interconnection Facilities; and d. monitor the implementation of the Agreement and take appropriate action for breach thereof including revocation of guarantees, cancellation of Agreement, blacklisting etc e. provide all assistance to the Arbitrators as required for the performance of their duties and responsibilities; and f. perform any other responsibility (ies) as specified in this Agreement. 4.3 Time for Commencement and Completion: a. The TSP shall take all necessary steps to commence work on the Project from the Effective Date of the Agreement and shall achieve [Insert Name of the SPV] 26 ……2026Transmission Service Agreement Scheduled COD of the Project in accordance with the time schedule specified in Schedule 2 of this Agreement; b. The COD of each Element of the Project shall occur no later than the Scheduled COD or within such extended time to which the TSP shall be entitled under Article 4.4 hereto. 4.4 Extension of time: 4.4.1 In the event that the TSP is unable to perform its obligations for the reasons solely attributable to the Nodal Agency, the Scheduled COD shall be extended, by a ‘day to day’ basis, subject to the provisions of Article 13. 4.4.2 In the event that an Element or the Project cannot be commissioned by its Scheduled COD on account of any Force Majeure Event as per Article 11, the Scheduled COD shall be extended, by a ‘day to day’ basis for a period of such Force Majeure Event. Alternatively, if deemed necessary, the Nodal Agency may terminate the Agreement as per the provisions of Article 13.4 by giving a Termination Notice to the TSP, in writing, of at least seven (7) days, with a copy to CEA and the Lenders’ Representative in order to enable the Lenders to exercise right of substitution in accordance with Article 15.3 of this Agreement. 4.4.3 If the Parties have not agreed, within thirty (30) days after the affected Party’s performance has ceased to be affected by the relevant circumstance, on how long the Scheduled COD should be deferred by, any Party may raise the Dispute to be resolved in accordance with Article 16. 4.5 Metering Arrangements: 4.5.1 The TSP shall comply with all the provisions of the IEGC and the Central Electricity Authority (Installation and Operation of Meters) Regulations, 2006 as amended from time to time, with regard to the metering arrangements for the Project. The TSP shall fully cooperate with the CTU / STU / RLDC and extend all necessary assistance in taking meter readings. 4.6 Interconnection Facilities: 4.6.1 Subject to the terms and conditions of this Agreement, the TSP shall be responsible for connecting the Project with the interconnection point(s) specified in Schedule 1 of this Agreement. The Interconnection Facilities shall be developed as per the scope of work and responsibilities assigned in Schedule 1 of this Agreement. The Nodal Agency shall be responsible for coordinating to make available the Interconnection Facilities. [Insert Name of the SPV] 27 ……2026Transmission Service Agreement 4.6.2 In order to remove any doubts, it is made clear that the obligation of the TSP within the scope of the project is to construct the Project as per Schedule-1 of this Agreement and in particular to connect it to the Interconnection Facilities as specified in this Agreement. [Insert Name of the SPV] 28 ……2026Transmission Service Agreement ARTICLE: 5 5 CONSTRUCTION OF THE PROJECT 5.1 TSP’s Construction Responsibilities: 5.1.1 The TSP, at its own cost and expense, shall be responsible for designing, constructing, erecting, testing and commissioning each Element of the Project by the Scheduled COD in accordance with the Regulations and other applicable Laws specified in Article 4.1 of this Agreement. 5.1.2 The TSP acknowledges and agrees that it shall not be relieved from any of its obligations under this Agreement or be entitled to any extension of time or any compensation whatsoever by reason of the unsuitability of the Site or Transmission Line route(s). 5.1.3 The TSP shall be responsible for obtaining all Consents, Clearances and Permits related but not limited to road / rail / river / canal / power line / crossings, Power and Telecom Coordination Committee (PTCC), defence, civil aviation, right of way / way-leaves and environmental & forest clearances from relevant authorities required for developing, financing, constructing, maintaining/ renewing all such Consents, Clearances and Permits in order to carry out its obligations under this Agreement in general and shall furnish to the Nodal Agency such copy/ies of each Consents, Clearances and Permits, on demand. Nodal Agency shall provide letters of recommendation to the concerned Indian Governmental Instrumentality, as may be requested by the TSP from time to time for obtaining the Consents, Clearances and Permits required for the Project. 5.1.4 The TSP shall be responsible for: (a) acquisition of land for location specific substations, switching stations or HVDC terminal or inverter stations. Also, the actual location of Greenfield substations (Switching Stations or HVDC Terminal or Inverter Stations) for a generation pooling substation and for load serving substations in the scope of TSP;  For a Generation Pooling Substation shall not be beyond 3 Km radius of the location proposed by the BPC in their Survey Report.  For Load Serving Substation within the scope of TSP shall not be beyond 5 Km radius of the location proposed by the BPC in their Survey Report. [Insert Name of the SPV] 29 ……2026Transmission Service Agreement  For an intermediate Substation shall not be beyond 10 Km radius of the location proposed by the BPC in their Survey Report. (b) final selection of Site including its geo-technical investigation; (c) survey and geo-technical investigation of line route in order to determine the final route of the Transmission Lines; (d) seeking access to the Site and other places where the Project is being executed, at its own risk and costs, including payment of any crop, tree compensation or any other compensation as may be required. 5.1.5 In case the Project involves any resettlement and rehabilitation, the resettlement and rehabilitation package will be implemented by the State Government authorities, for which the costs is to be borne by the TSP and no changes would be allowed in the Transmission Charges on account of any variation in the resettlement and rehabilitation cost. The TSP shall provide assistance on best endeavour basis, in implementation of the resettlement and rehabilitation package, if execution of such package is in the interest of expeditious implementation of the Project and is beneficial to the Project affected persons. 5.2 Appointing Contractors: 5.2.1 The TSP shall conform to the requirements as provided in this Agreement while appointing Contractor(s) for procurement of goods & services. 5.2.2 The appointment of such Contractor(s) shall neither relieve the TSP of any of its obligations under this Agreement nor make the Nodal Agency liable for the performance of such Contractor(s). 5.3 Monthly Progress Reporting: The TSP shall provide to the CEA, Nodal Agency & Independent Engineer, on a monthly basis, progress reports along with likely completion date of each Element with regard to the Project and its execution (in accordance with prescribed form). The Nodal Agency/ CEA shall monitor the development of the Project for its timely completion for improving and augmenting the electricity system as a part of its statutory responsibility. 5.4 Quality of Workmanship: The TSP shall ensure that the Project is designed, built and completed in a good workmanship using sound engineering and construction practices, and using only materials and equipment that are new and manufactured as [Insert Name of the SPV] 30 ……2026Transmission Service Agreement per the MQP and following approved FQP for erection, testing & commissioning and complying with Indian /International Standards such that, the useful life of the Project will be at least thirty five (35) years from the COD of the Project. The TSP shall ensure that all major substation equipment / component (e.g. transformers, reactors, Circuit Breakers, Instrument Transformers (IT), Surge Arresters (SA), Protection relays, clamps & connectors etc.), equipment in terminal stations of HVDC installations including Thyristor/ IGBT valves, Converter Transformers, smoothing reactors, Transformer bushings and wall bushings, GIS bus ducts, towers and gantry structures and transmission towers or poles and line materials (conductors, earthwire, OPGW, insulator, accessories for conductors, OPGW & earthwires, hardware fittings for insulators, aviation lights etc), facilities and system shall be designed, constructed and tested (Type test, Routine tests, Factory Acceptance Test (FAT)) in accordance with relevant CEA Regulations and Indian Standards. In case Indian Standards for any particular equipment/ system/ process is not available, IEC/ IEEE or equivalent International Standards and Codes shall be followed. 5.5 Progress Monitoring & Quality Assurance: 5.5.1 The Project Execution Plan submitted by the TSP in accordance with Article 3.1.3 c) shall comprise of detailed schedule of all the equipments/items /materials required for the Project, right from procurement of raw material till the dispatch from works and receipt at the site. Further, it should also include various stages of the construction schedule up to the commissioning of the Project. 5.5.2 Nodal Agency, CEA & Independent Engineer shall have access at all reasonable times to the Site and to the Manufacturer’s works and to all such places where the Project is being executed. 5.5.3 Independent Engineer shall ensure conformity of the conductor specifications with the functional specifications specified in RFP. 5.5.4 The Independent Engineer shall monitor the following during construction of the Project: a) Quality of equipments, material, foundation, structures and workmanship etc. as laid down in Article 5.4 and 6.1.4 of the TSA. Specifically, quality of Sub-station equipments, transmission line material and workmanship etc. would be checked in accordance with the Article 5.4. b) Progress in the activities specified in Condition Subsequent [Insert Name of the SPV] 31 ……2026Transmission Service Agreement c) Verification of readiness of the elements including the statutory clearances & completion of civil works, fixing of all components and finalisation of punch points (if any) prior to charging of the elements d) Progress of construction of substation and Transmission Lines 5.5.5 The progress shall be reviewed by the Independent Engineer against the Project Execution Plan. The Independent Engineer shall prepare its report on monthly basis and submit the same to Nodal Agency highlighting the progress achieved till the end of respective month vis-à-vis milestone activities, areas of concern, if any, which may result in delay in the timely completion of the Project. Based on the progress, Nodal Agency and/ or CEA shall issue written instructions to the TSP to take corrective measures, as may be prudent for the timely completion of the Project. In case of any deficiency, the Nodal Agency would be at liberty to take action in accordance with the procedure of this Agreement. 5.5.6 For any delay in commissioning any critical Element(s), as identified in Schedule 1 & Schedule 2 of this Agreement, beyond a period of 45 days shall lead to a sequestration of 10% of the Contract Performance Guarantee. 5.6 Site regulations and Construction Documents The TSP shall abide by the Safety Rules and Procedures as mentioned in Schedule 3 of this Agreement The TSP shall retain at the Site and make available for inspection at all reasonable times, copies of the Consents, Clearances and Permits, construction drawings and other documents related to construction. 5.7 Supervision of work: The TSP shall provide all necessary superintendence for execution of the Project and its supervisory personnel shall be available to provide full-time superintendence for execution of the Project. The TSP shall provide skilled personnel who are experienced in their respective fields. 5.8 Remedial Measures: The TSP shall take all necessary actions for remedying the shortfall in achievement of timely progress in execution of the Project, if any, as intimated by the Independent Engineer and/ or CEA and/ or the Nodal Agency. However, such intimation by the Independent Engineer and/ or CEA and/ or the Nodal Agency and the subsequent effect of such remedial measures carried out by the TSP shall not relieve the TSP of its obligations in the Agreement. Independent Engineer and/ or CEA and/ or the Nodal [Insert Name of the SPV] 32 ……2026Transmission Service Agreement Agency may carry out random inspections during the Project execution, as and when deemed necessary by it. If the shortfalls as intimated to the TSP are not remedied to the satisfaction of the CEA and/ or the Nodal Agency, this Agreement may be terminated by the Nodal Agency by giving a Termination Notice to the TSP, in writing, of at least seven (7) days, with a copy to CEA and the Lenders’ Representative in order to enable the Lenders to exercise right of substitution in accordance with Article 15.3 of this Agreement. [Insert Name of the SPV] 33 ……2026Transmission Service Agreement ARTICLE: 6 6 CONNECTION AND COMMISSIONING OF THE PROJECT 6.1 Connection with the Inter-Connection Facilities: 6.1.1 The TSP shall give the RLDC(s), CTU, / STU, as the case may be, and any other agencies as required, at least sixty (60) days advance written notice of the date on which it intends to connect an Element of the Project, which date shall not be earlier than its Scheduled COD or Schedule COD extended as per Article 4.4.1 & 4.4.2 of this Agreement, unless mutually agreed to by Parties. Further, any preponing of COD of any element prior to Scheduled COD must be approved by the Nodal Agency. 6.1.2 The RLDC / SLDC (as the case may be) or the CTU / STU (as the case may be), for reasonable cause, including non-availability of Interconnection Facilities as per Article 4.2, can defer the connection for up to fifteen (15) days from the date notified by the TSP pursuant to Article 6.1.1, if it notifies to the TSP in writing, before the date of connection, of the reason for the deferral and when the connection is to be rescheduled. However, no such deferment on one or more occasions would be for more than an aggregate period of thirty (30) days. Further, the Scheduled COD would be extended as required, for all such deferments on “day to day” basis. 6.1.3 Subject to Articles 6.1.1 and 6.1.2, any Element of Project may be connected with the Interconnection Facilities when: a. it has been completed in accordance with this Agreement and the Connection Agreement; b. it meets the Grid Code, Central Electricity Authority (Technical Standards for Connectivity to the Grid) Regulations, 2007 as amended from time to time and all other Indian legal requirements, and c. The TSP has obtained the approval in writing of the Electrical Inspector certifying that the Element is ready from the point of view of safety of supply and can be connected with the Interconnection Facilities. d. It has satisfactorily met all the testing requirements as per Articles 6.1.4 6.1.4 Site Acceptance Test (SAT)/ pre-commissioning tests of all major substation equipment, component, system, facilities shall be successfully [Insert Name of the SPV] 34 ……2026Transmission Service Agreement carried out before commissioning. The Type tests, FAT and SAT reports should be available at the substation / terminal station of HVDC installations for ready reference of operation and maintenance staff and has to be made available to the Independent Engineer appointed for quality monitoring or their authorised representatives, as and when they wish to examine the same. 6.2 Commercial Operation: 6.2.1 An Element of the Project shall be declared to have achieved COD twenty four (24) hours following the connection of the Element with the Interconnection Facilities pursuant to Article 6.1 or seven (7) days after the date on which it is declared by the TSP to be ready for charging but is not able to be charged for reasons not attributable to the TSP subject to Article 6.1.2. Provided that an Element shall be declared to have achieved COD only after all the Element(s), if any, which are pre-required to have achieved COD as defined in Schedule 2 of this Agreement, have been declared to have achieved their respective COD. 6.2.2 Once any Element of the Project has been declared to have achieved deemed COD as per Article 6.2.1 above, such Element of the Project shall be deemed to have Availability equal to the Target Availability till the actual charging of the Element and to this extent, TSP shall be eligible for the Monthly Transmission Charges applicable for such Element 6.3 Compensation for Direct Non Natural Force Majeure Event or Indirect Non Natural Force Majeure Event or Natural Force Majeure Event (affecting the Nodal Agency) 6.3.1 If the TSP is otherwise ready to connect the Element(s) of the Project and has given due notice, as per provisions of Article 6.1.1, to the concerned agencies of the date of intention to connect the Element(s) of the Project, where such date is not before the Scheduled COD, but is not able to connect the Element(s) of the Project by the said date specified in the notice, due to Direct Non Natural Force Majeure Event or Indirect Non Natural Force Majeure Event or Natural Force Majeure Event affecting the Nodal Agency, provided such Direct Non Natural Force Majeure Event or Indirect Non Natural Force Majeure Event or Natural Force Majeure Event affecting the Nodal Agency has continued for a period of more than three (3) continuous or non-continuous Months, the TSP shall, until the effects of the Direct Non Natural Force Majeure Event or of Indirect Non Natural Force Majeure Event or Natural Force Majeure Event affecting the Nodal [Insert Name of the SPV] 35 ……2026Transmission Service Agreement Agency no longer prevent the TSP from connecting the Element(s) of the Project, be deemed to have achieved COD relevant to that date and to this extent, be deemed to have been providing Transmission Service with effect from the date notified, and shall be treated as follows: a. In case of delay due to Direct Non Natural Force Majeure Event, TSP is entitled for Transmission Charges calculated on Target Availability for the period of such events in excess of three (3) continuous or non continuous Months in the manner provided in (c) below. b. In case of delay due to Indirect Non Natural Force Majeure Event or Natural Force Majeure Event affecting the Nodal Agency, TSP is entitled for payment for debt service which is due under the Financing Agreements, subject to a maximum of Transmission Charges calculated on Target Availability, for the period of such events in excess of three (3) continuous or non continuous Months in the manner provided in (c) below. c. In case of delay due to Direct Non Natural Force Majeure Event or Indirect Non Natural Force Majeure Event or Natural Force Majeure Event affecting the Nodal Agency, the TSP is entitled for payments mentioned in (a) and (b) above, after commencement of Transmission Service, in the form of an increase in Transmission Charges. These amounts shall be paid from the date, being the later of a) the date of cessation of such Indirect Non Natural Force Majeure Event or Natural Force Majeure Event affecting the Nodal Agency and b) the completion of sixty (60) days from the receipt of the Financing Agreements by the Nodal Agency from the TSP. Provided such increase in Transmission Charges shall be so as to put the TSP in the same economic position as the TSP would have been in case the TSP had been paid amounts mentioned in (a) and (b) above in a situation where the Force Majeure Event had not occurred. For the avoidance of doubt, it is clarified that the charges payable under this Article 6.3.1 shall be recovered as per Sharing Regulations. 6.4 Liquidated Damages for Delay in achieving COD of Project: 6.4.1 If the TSP fails to achieve COD of any Element of the Project or the Project, by the Element’s / Project’s Scheduled COD or such Scheduled COD as extended under Articles 4.4.1 and 4.4.3, then the TSP shall pay to the Nodal Agency, a sum equivalent to 3.33% of Monthly Transmission Charges applicable for the Element of the Project [in case where no [Insert Name of the SPV] 36 ……2026Transmission Service Agreement Elements have been defined, to be on the Project as a whole] / Project, for each day of delay up to sixty (60) days of delay and beyond that time limit, at the rate of five percent (5%) of the Monthly Transmission Charges applicable to such Element / Project, as liquidated damages for such delay and not as penalty, without prejudice to any rights of the Nodal Agency under the Agreement. 6.4.2 The TSP’s maximum liability under this Article 6.4 shall be limited to the amount of liquidated damages calculated in accordance with Article 6.4.1 for and up to six (6) months of delay for the Element or the Project. Provided that, in case of failure of the TSP to achieve COD of the Element of the Project even after the expiry of six (6) months from its Scheduled COD, the provisions of Article 13 shall apply. 6.4.3 The TSP shall make payment to the Nodal Agency of the liquidated damages calculated pursuant to Article 6.4.1 within ten (10) days of the earlier of: a. the date on which the applicable Element achieves COD; or b. the date of termination of this Agreement. The payment of such damages shall not relieve the TSP from its obligations to complete the Project or from any other obligation and liabilities under the Agreement. 6.4.4 If the TSP fails to pay the amount of liquidated damages to the Nodal Agency within the said period of ten (10) days, the Nodal Agency shall be entitled to recover the said amount of the liquidated damages by invoking the Contract Performance Guarantee. If the then existing Contract Performance Guarantee is for an amount which is less than the amount of the liquidated damages payable by the TSP to the Nodal Agency under this Article 6.3 and the TSP fails to make payment of the balance amount of the liquidated damages not covered by the Contract Performance Guarantee, then such balance amount shall be deducted from the Transmission Charges payable to the TSP. The right of the Nodal Agency to encash the Contract Performance Guarantee is without prejudice to the other rights of the Nodal Agency under this Agreement. 6.4.5 For avoidance of doubt, it is clarified that amount payable by TSP under this Article is over and above the penalty payable by TSP under Article 5.5.6 of this Agreement. 6.5 Return of Contract Performance Guarantee [Insert Name of the SPV] 37 ……2026Transmission Service Agreement 6.5.1 The Contract Performance Guarantee as submitted by TSP in accordance with Article 3.1.1 shall be released by the Nodal Agency within three (3) months from the COD of the Project. In the event of delay in achieving Scheduled COD of any of the Elements by the TSP (otherwise than due to reasons as mentioned in Article 3.1.3 or Article 11) and consequent part invocation of the Contract Performance Guarantee by the Nodal Agency, Nodal Agency shall release the Contract Performance Guarantee, if any remaining unadjusted, after the satisfactory completion by the TSP of all the requirements regarding achieving the Scheduled COD of the remaining Elements of the Project. It is clarified that the Nodal Agency shall also return / release the Contract Performance Guarantee in the event of (i) applicability of Article 3.3.2 to the extent the Contract Performance Guarantee is valid for an amount in excess of Rs.196.75 Crore (Rupees One Hundred Ninety-Six Crore and Seventy-Five Lakh Only) or (ii) termination of this Agreement by the Nodal Agency as mentioned under Article 3.3.4 of this Agreement. 6.5.2 The release of the Contract Performance Guarantee shall be without prejudice to other rights of the Nodal Agency under this Agreement. [Insert Name of the SPV] 38 ……2026Transmission Service Agreement ARTICLE: 7 7 OPERATION AND MAINTENANCE OF THE PROJECT 7.1 Operation and Maintenance of the Project: The TSP shall be responsible for ensuring that the Project is operated and maintained in accordance with the regulations made by the Commission and CEA from time to time and provisions of the Act. [Insert Name of the SPV] 39 ……2026Transmission Service Agreement ARTICLE: 8 8 AVAILABILITY OF THE PROJECT 8.1 Calculation of Availability of the Project: Calculation of Availability for the Elements and for the Project, as the case may be, shall be as per Appendix –IV to Central Electricity Regulatory Commission (Terms and Conditions of Tariff) Regulations, 2024, as applicable on the Bid Deadline and as appended in Schedule 6 of this Agreement. 8.2 Target Availability: The Target Availability of each Element and the Project shall be 98%. Payment of monthly Transmission charges based on actual availability will be calculated as per para 1.2 of Schedule 4 of this Agreement. If the availability of any Element or the Project is below the Target Availability, for six consecutive months in a Contract Year, the DIC(s) or the Nodal Agency may issue a show cause notice to the TSP, asking them to show cause as to why the Transmission Service Agreement be not terminated, and if no satisfactory cause is shown it may terminate the Agreement. If the Nodal Agency is of the opinion that the transmission system is of critical importance, it may carry out or cause to carry the operation and maintenance of transmission system at the risk and cost of TSP. [Insert Name of the SPV] 40 ……2026Transmission Service Agreement ARTICLE: 9 9 INSURANCES 9.1 Insurance: 9.1.1 The TSP shall effect and maintain or cause to be effected and maintained during the Construction Period and the Operating Period, adequate Insurances against such risks, with such deductibles including but not limited to any third party liability and endorsements and co- beneficiary/insured, as may be necessary under a. any of the Financing Agreements, b. the Laws, and c. in accordance with Prudent Utility Practices. The Insurances shall be taken effective from a date prior to the date of the Financial Closure till the Expiry Date. 9.2 Evidence of Insurance cover: 9.2.1 The TSP shall furnish to the Nodal Agency copies of certificates and policies of the Insurances, as and when the Nodal Agency may seek from the TSP as per the terms of Article 9.1 9.3 Application of Insurance Proceeds: 9.3.1 Save as expressly provided in this Agreement, the policies of Insurances and the Financing Agreements, the proceeds of any insurance claim made due to loss or damage to the Project or any part of the Project shall be first applied to reinstatement, replacement or renewal of such loss or damage. 9.3.2 If a Natural Force Majeure Event renders the Project no longer economically and technically viable and the insurers under the Insurances make payment on a “total loss” or equivalent basis, the portion of the proceeds of such Insurance available to the TSP (after making admissible payments to the Lenders as per the Financing Agreements) shall be allocated only to the TSP. Nodal Agency and / or concerned Designated ISTS Customers shall have no claim on such proceeds of the Insurance. 9.3.3 Subject to the requirements of the Lenders under the Financing Agreements, any dispute or difference between the Parties as to whether the Project is no longer economically and technically viable due to a Force [Insert Name of the SPV] 41 ……2026Transmission Service Agreement Majeure Event or whether that event was adequately covered in accordance with this Agreement by the Insurances shall be determined in accordance with Article 16. 9.4 Effect on liability of the Nodal Agency / Designated ISTS Customers 9.4.1 The Nodal Agency and / or the Designated ISTS Customers shall have no financial obligations or liability whatsoever towards the TSP in respect of this Article 9. [Insert Name of the SPV] 42 ……2026Transmission Service Agreement ARTICLE: 10 10 BILLING AND PAYMENT OF TRANSMISSION CHARGES 10.1 Subject to provisions of this Article 10, the Monthly Transmission Charges shall be paid to the TSP, in Indian Rupees, on monthly basis as per the provisions of the Sharing Regulations, from the date on which an Element(s) has achieved COD until the Expiry Date of this Agreement, unless terminated earlier and in line with the provisions of Schedule 4 of this Agreement. 10.2 Calculation of Monthly Transmission Charges: The Monthly Transmission Charges for each Contract Year including Incentive & Penalty payment shall be calculated in accordance with the provisions of Schedule 4 of this Agreement. 10.3 Rebate & Late Payment Surcharge: The rebate and late payment surcharge shall be governed as per Sharing regulations. 10.4 Disputed Bills, Default in payment by the Designated ISTS Customers & Annual Reconciliation: Any Disputed Bill, Default in payment by the Designated ISTS Customers & Annual Reconciliation shall be governed as per Sharing Regulations. [Insert Name of the SPV] 43 ……2026Transmission Service Agreement ARTICLE: 11 11 FORCE MAJEURE 11.1 Definitions 11.1.1 The following terms shall have the meanings given hereunder. 11.2 Affected Party 11.2.1 An Affected Party means any Party whose performance has been affected by an event of Force Majeure. 11.2.2 Any event of Force Majeure shall be deemed to be an event of Force Majeure affecting the TSP only if the Force Majeure event affects and results in, late delivery of machinery and equipment for the Project or construction, completion, commissioning of the Project by Scheduled COD and/or operation thereafter; 11.3 Force Majeure A ‘Force Majeure’ means any event or circumstance or combination of events and circumstances including those stated below that wholly or partly prevents or unavoidably delays an Affected Party in the performance of its obligations/ roles under this Agreement, but only if and to the extent that such events or circumstances are not within the reasonable control, directly or indirectly, of the Affected Party and could not have been avoided if the Affected Party had taken reasonable care or complied with Prudent Utility Practices: (a) Natural Force Majeure Events: i. act of God, including, but not limited to drought, fire and explosion (to the extent originating from a source external to the Site), earthquake, volcanic eruption, landslide, flood, cyclone, typhoon, tornado, or exceptionally adverse weather conditions, which are in excess of the statistical measures for the last hundred (100) years; and ii. epidemic/ pandemic notified by Indian Governmental Instrumentality. (b) Non-Natural Force Majeure Events : i. Direct Non–Natural Force Majeure Events  Nationalization or compulsory acquisition by any Indian [Insert Name of the SPV] 44 ……2026Transmission Service Agreement Governmental Instrumentality of any material assets or rights of the Affected Party; or  the unlawful, unreasonable or discriminatory revocation of, or refusal to renew, any Consents, Clearances and Permits required by the Affected Party to perform their obligations/ roles under the RFP Project Documents or any unlawful, unreasonable or discriminatory refusal to grant any other Consents, Clearances and Permits required for the development/ operation of the Project, provided that a Competent Court of Law declares the revocation or refusal to be unlawful, unreasonable and discriminatory and strikes the same down; or  any other unlawful, unreasonable or discriminatory action on the part of an Indian Governmental Instrumentality which is directed against the Project, provided that a Competent Court of Law declares the action to be unlawful, unreasonable and discriminatory and strikes the same down. ii. Indirect Non - Natural Force Majeure Events  act of war (whether declared or undeclared), invasion, armed conflict or act of foreign enemy, blockade, embargo, revolution, riot, insurrection, terrorist or military action; or  radio active contamination or ionising radiation originating from a source in India or resulting from any other Indirect Non Natural Force Majeure Event mentioned above, excluding circumstances where the source or cause of contamination or radiation is brought or has been brought into or near the Site by the Affected Party or those employed or engaged by the Affected Party; or  industry-wide strikes and labour disturbances, having a nationwide impact in India. 11.4 Force Majeure Exclusions 11.4.1 Force Majeure shall not include (i) any event or circumstance which is within the reasonable control of the Parties and (ii) the following conditions, except to the extent that they are consequences of an event of Force Majeure: (a) Unavailability, late delivery, or changes in cost of the machinery, [Insert Name of the SPV] 45 ……2026Transmission Service Agreement equipment, materials, spare parts etc. for the Project; (b) Delay in the performance of any Contractors or their agents; (c) Non-performance resulting from normal wear and tear typically experienced in transmission materials and equipment; (d) Strikes or labour disturbance at the facilities of the Affected Party; (e) Insufficiency of finances or funds or the Agreement becoming onerous to perform; and (f) Non-performance caused by, or connected with, the Affected Party’s: i. negligent or intentional acts, errors or omissions; ii. failure to comply with an Indian Law; or iii. breach of, or default under this Agreement or any Project Documents. (g) Any error or omission in the survey report provided by BPC during the bidding process. 11.5 Notification of Force Majeure Event 11.5.1 The Affected Party shall give notice to the other Party of any event of Force Majeure as soon as reasonably practicable, but not later than seven (7) days after the date on which such Party knew or should reasonably have known of the commencement of the event of Force Majeure. If an event of Force Majeure results in a breakdown of communications rendering it unreasonable to give notice within the applicable time limit specified herein, then the Party claiming Force Majeure shall give such notice as soon as reasonably practicable after reinstatement of communications, but not later than one (1) day after such reinstatement. Provided that, such notice shall be a pre-condition to the Affected Party’s entitlement to claim relief under this Agreement. Such notice shall include full particulars of the event of Force Majeure, its effects on the Party claiming relief and the remedial measures proposed. The Affected Party shall give the other Party regular reports on the progress of those remedial measures and such other information as the other Party may reasonably request about the Force Majeure. 11.5.2 The Affected Party shall give notice to the other Party of (i) the cessation of the relevant event of Force Majeure; and (ii) the cessation of the effects [Insert Name of the SPV] 46 ……2026Transmission Service Agreement of such event of Force Majeure on the performance of its rights or obligations/ roles under this Agreement, as soon as practicable after becoming aware of each of these cessations. 11.6 Duty to perform and duty to mitigate To the extent not prevented by a Force Majeure Event, the Affected Party shall continue to perform its obligations/ roles as provided in this Agreement. The Affected Party shall use its reasonable efforts to mitigate the effect of any event of Force Majeure as soon as practicable. 11.7 Available Relief for a Force Majeure Event Subject to this Article 11, (a) no Party shall be in breach of its obligations/ roles pursuant to this Agreement to the extent that the performance of its obligations/ roles was prevented, hindered or delayed due to a Force Majeure Event; (b) each Party shall be entitled to claim relief for a Force Majeure Event affecting its performance in relation to its obligations/ roles under Articles 3.3.4, 4.4.2 and 6.3.1 of this Agreement. (c) For the avoidance of doubt, it is clarified that the computation of Availability of the Element(s) under outage due to Force Majeure Event, as per Article 11.3 affecting the TSP shall be as per Appendix –IV to Central Electricity Regulatory Commission (Terms and Conditions of Tariff) Regulations, 2024 as on Bid Deadline. For the event(s) for which the Element(s) is/are deemed to be available as per Appendix –IV to Central Electricity Regulatory Commission (Terms and Conditions of Tariff) Regulations, 2024, then the Transmission Charges, as applicable to such Element(s), shall be payable as per Schedule 4, for the duration of such event(s). (d) For so long as the TSP is claiming relief due to any Force Majeure Event under this Agreement, the Nodal Agency may, if it so desires, from time to time on one (1) day notice, inspect the Project and the TSP shall provide the Nodal Agency’s personnel with access to the Project to carry out such inspections. (e) For avoidance of doubt, the TSP acknowledges that for extension of Scheduled COD a period up to one hundred eighty (180) days due to Force Majeure event, no compensation on the grounds such as interest cost, incident expenditure, opportunity cost will be made to the TSP. However, if Scheduled COD is extended beyond a period of one [Insert Name of the SPV] 47 ……2026Transmission Service Agreement hundred eighty (180) days due to Force Majeure event, the TSP will be allowed to recover the interest cost during construction corresponding to the period exceeding one hundred eighty (180) days by adjustment in the Transmission Charges in accordance with Schedule 9. [Insert Name of the SPV] 48 ……2026Transmission Service Agreement ARTICLE: 12 12 CHANGE IN LAW 12.1 Change in Law 12.1.1 Change in Law means the occurrence of any of the following after the Bid Deadline resulting into any additional recurring / non-recurring expenditure by the TSP or any savings of the TSP:  the enactment, coming into effect, adoption, promulgation, amendment, modification or repeal (without re-enactment or consolidation) in India, of any Law, including rules and regulations framed pursuant to such Law, subject to the provisions under Article 12.1.2;  a change in the interpretation or application of any Law by any Indian Governmental Instrumentality having the legal power to interpret or apply such Law, or any Competent Court of Law;  the imposition of a requirement for obtaining any Consents, Clearances and Permits which was not required earlier;  a change in the terms and conditions prescribed for obtaining any Consents, Clearances and Permits or the inclusion of any new terms or conditions for obtaining such Consents, Clearances and Permits;  any change in the licensing regulations of the Commission, under which the Transmission License for the Project was granted if made applicable by such Commission to the TSP;  change in wind zone; or  any change in tax or introduction of any tax made applicable for providing Transmission Service by the TSP as per the terms of this Agreement. 12.1.2 Notwithstanding anything contained in this Agreement, Change in Law shall not cover any change: a) Taxes on corporate income; and b) Withholding tax on income or dividends distributed to the shareholders of the TSP. [Insert Name of the SPV] 49 ……2026Transmission Service Agreement 12.2 Relief for Change in Law 12.2.1 During Construction Period, the impact of increase/decrease in the cost of the Project on the Transmission Charges shall be governed by the formula given in Schedule 9 of this Agreement. 12.2.2 During the Operation Period: During the operation period, if as a result of Change in Law, the TSP suffers or is benefited from a change in costs or revenue, the aggregate financial effect of which exceeds 0.30% (zero point three percent) of the Annual Transmission Charges in aggregate for a Contract Year, the TSP may notify so to the Nodal Agency and propose amendments to this Agreement so as to place the TSP in the same financial position as it would have enjoyed had there been no such Change in Law resulting in change in costs or revenue as aforesaid. 12.2.3 For any claims made under Articles 12.2.1 and 12.2.2 above, the TSP shall provide to the Nodal Agency documentary proof of such increase / decrease in cost of the Project / revenue for establishing the impact of such Change in Law. In cases where Change in Law results in decrease of cost and it comes to the notice of Nodal Agency that TSP has not informed Nodal Agency about such decrease in cost, Nodal Agency may initiate appropriate claim. 12.3 Notification of Change in Law: 12.3.1 If the TSP is affected by a Change in Law in accordance with Article 12.1 and wishes to claim relief for such Change in Law under this Article 12, it shall give notice to Nodal Agency of such Change in Law as soon as reasonably practicable after becoming aware of the same. 12.3.2 The TSP shall also be obliged to serve a notice to the Nodal Agency even when it is beneficially affected by a Change in Law. 12.3.3 Any notice served pursuant to Articles 12.3.1 and 12.3.2 shall provide, amongst other things, precise details of the Change in Law and its estimated impact on the TSP. 12.4 Payment on account of Change in Law 12.4.1 The payment for Change in Law shall be through a separate Bill. However, in case of any change in Monthly Transmission Charges by reason of Change in Law, as determined in accordance with this Agreement, the Bills to be raised by the Nodal Agency after such change in Transmission [Insert Name of the SPV] 50 ……2026Transmission Service Agreement Charges shall appropriately reflect the changed Monthly Transmission Charges. [Insert Name of the SPV] 51 ……2026Transmission Service Agreement ARTICLE: 13 13 EVENTS OF DEFAULT AND TERMINATION 13.1 TSP’s Event of Default The occurrence and continuation of any of the following events shall constitute a TSP Event of Default, unless any such TSP Event of Default occurs as a result of any non-fulfilment of its obligations as prescribed under this Agreement by the Nodal Agency or a Force Majeure Event: a. After having taken up the construction of the Project, the abandonment by the TSP or the TSP's Contractors of the construction of the Project for a continuous period of two (2) months and such default is not rectified within thirty (30) days from the receipt of notice from the Nodal Agency in this regard; b. The failure to commission any Element of the Project by the date falling six (6) months after its Scheduled COD unless extended by Nodal Agency as per provisions of this Agreement; c. If the TSP: i. assigns, mortgages or charges or purports to assign, mortgage or charge any of its assets or rights related to the Project in contravention of the provisions of this Agreement; or ii. transfers or novates any of its obligations pursuant to this Agreement, in a manner contrary to the provisions of this Agreement; Except where such transfer is in pursuance of a Law and  it does not affect the ability of the transferee to perform, and such transferee has the financial and technical capability to perform, its obligations under this Agreement;  is to a transferee who assumes such obligations under the Project and this Agreement remains effective with respect to the transferee; d. If: i. The TSP becomes voluntarily or involuntarily the subject of any bankruptcy or insolvency or winding up proceedings [Insert Name of the SPV] 52 ……2026Transmission Service Agreement and such proceedings remain uncontested for a period of thirty (30) days; or ii. any winding up or bankruptcy or insolvency order is passed against the TSP; or iii. the TSP goes into liquidation or dissolution or a receiver or any similar officer is appointed over all or substantially all of its assets or official liquidator is appointed to manage its affairs, pursuant to Law, Provided that a dissolution or liquidation of the TSP will not be a TSP’s Event of Default, where such dissolution or liquidation of the TSP is for the purpose of a merger, consolidation or reorganization with the prior approval of the Commission as per the provisions of Central Electricity Regulatory Commission (Procedure, terms and Conditions for grant of Transmission License and other related matters) Regulations, 2006 or as amended from time to time; or e. Failure on the part of the TSP to comply with the provisions of Article 19.1 of this Agreement; or f. the TSP repudiates this Agreement and does not rectify such breach even within a period of thirty (30) days from a notice from the Nodal Agency in this regard; or g. after Commercial Operation Date of the Project, the TSP fails to achieve monthly Target Availability of 98%, for a period of six (6) consecutive months or within a non-consecutive period of six (6) months within any continuous aggregate period of eighteen (18) months except where the Availability is affected by Force Majeure Events as per Article 11; or h. any of the representations and warranties made by the TSP in Article 17 of this Agreement being found to be untrue or inaccurate. Further, in addition to the above, any of the undertakings submitted by the Selected Bidder at the time of submission of the Bid being found to be breached or inaccurate, including but not limited to undertakings from its Parent Company / Affiliates related to the minimum equity obligation; or i. the TSP fails to complete / fulfil all the activities / conditions within the specified period as per Article 3; or [Insert Name of the SPV] 53 ……2026Transmission Service Agreement j. except for the reasons solely attributable to Nodal Agency, the TSP is in material breach of any of its obligations under this Agreement and such material breach is not rectified by the TSP within thirty (30) days of receipt of notice in this regard from the Nodal Agency; or k. TSP fails to take the possession of the land required for location specific substations, switching stations or HVDC terminal or inverter stations and / or fails to pay the requisite price to the parties and / or any State Government authority from whom the land is acquired, within twelve (12) months from the Effective Date. 13.2 Termination Procedure for TSP Event of Default a. Upon the occurrence and continuance of any TSP’s Event of Default under Article 13.1 the Nodal Agency may serve notice on the TSP, with a copy to the CEA and the Lenders’ Representative, of their intention to terminate this Agreement (a "Nodal Agency’s Preliminary Termination Notice"), which shall specify in reasonable detail, the circumstances giving rise to such Nodal Agency’s Preliminary Termination Notice. b. Following the issue of a Nodal Agency’s Preliminary Termination Notice, the Consultation Period shall apply and would be for the Parties to discuss as to what steps shall be taken with a view to mitigate the consequences of the relevant Event of Default having regard to all the circumstances. c. During the Consultation Period, the Parties shall, save as otherwise provided in this Agreement, continue to perform their respective obligations/ roles under this Agreement, and the TSP shall not remove any material, equipment or any part of the Project, without prior consent of the Nodal Agency. Following the expiry of the Consultation Period, unless the Parties shall have otherwise agreed to the contrary or the circumstances giving rise to Nodal Agency’s Preliminary Termination Notice shall have ceased to exist or shall have been remedied, this Agreement may be terminated by the Nodal Agency by giving a Termination Notice to the TSP, in writing, of at least seven (7) days, with a copy to CEA and the Lenders’ Representative in order to enable the Lenders to exercise right of substitution in accordance with Article 15.3 of this Agreement. [Insert Name of the SPV] 54 ……2026Transmission Service Agreement Further, the Nodal Agency may also initiate proceedings to blacklist the TSP & its Affiliates from participation in any RFP issued by BPCs for a period of 5 years. 13.3 Procedure for Nodal Agency’s non-fulfilment of Role a. Upon the Nodal Agency not being able to fulfil its role under Article 4.2, the TSP may serve notice on the Nodal Agency, with a copy to CEA and the Lenders’ Representative (a "TSP’s Preliminary Notice"), which notice shall specify in reasonable detail the circumstances giving rise to such non-fulfilment of role by the Nodal Agency. b. Following the issue of a TSP’s Preliminary Notice, the Consultation Period shall apply. c. The Consultation Period would be for the Parties to discuss as to what steps shall be taken with a view to mitigate the consequences of the relevant non-fulfilment of role by the Nodal Agency including giving time extension to TSP, having regard to all the circumstances. d. During the Consultation Period, both Parties shall, save as otherwise provided in this Agreement, continue to perform their respective obligations/ roles under this Agreement. 13.4 Termination due to Force Majeure 13.4.1 In case the Parties could not reach an agreement pursuant to Articles 3.3.4 and 4.4.2 of this Agreement and the Force Majeure Event or its effects continue to be present, the Nodal Agency shall have the right to cause termination of the Agreement. In case of such termination, the Contract Performance Guarantee shall be returned to the TSP as per the provisions of Article 6.5.1. 13.4.2 In case of termination of this Agreement, the TSP shall provide to the Nodal Agency the full names and addresses of its Contractors as well as complete designs, design drawings, manufacturing drawings, material specifications and technical information, as required by the Nodal Agency within thirty (30) days of Termination Notice. 13.5 Termination or amendment due to non-requirement of any Element or Project during construction 13.5.1 In case any Element or Project, which is under construction, is no longer required due to any reason whatsoever, the Nodal Agency may issue a notice to this effect to the TSP. [Insert Name of the SPV] 55 ……2026Transmission Service Agreement 13.5.2 Nodal agency may also issue notice to the TSP seeking their response to the proposed termination/ amendment (as the case may be) of the Agreement. The Nodal Agency shall issue copy of such notice to Lenders. In the notice, Nodal Agency shall also include an assessment of the physical progress made by TSP in the Element/ Project (as the case may be) that is no longer required. 13.5.3 The TSP shall neither carry out further investment nor carry out any work on the Element/ Project (as the case may be) that is no longer required after delivery of the notice. 13.5.4 After taking into account the comments of the TSP, the Nodal Agency may terminate the Agreement or amend it if both Parties agree to the amendment. 13.6 Revocation of the Transmission License 13.6.1 The Commission may, as per the provisions of the Electricity Act, 2003, revoke the Transmission License of the ISTS Licensee. Further, in such a case, the Agreement shall be deemed to have been terminated. 13.7 Termination Payment 13.7.1 If Agreement is terminated on account of Force Majeure Events, non- requirement of any Element or Project during Construction, Nodal Agency’s non-fulfilment of Role & TSP’s Event of Default, the TSP shall be entitled for Termination Payment equivalent to valuation of Project Assets. Upon payment, the Nodal Agency shall take over the Project Assets. [Insert Name of the SPV] 56 ……2026Transmission Service Agreement ARTICLE: 14 14 LIABILITY AND INDEMNIFICATION 14.1 Indemnity 14.1.1 The TSP shall indemnify, defend and hold the Nodal Agency harmless against: (a) any and all third party claims, actions, suits or proceedings against the Nodal Agency for any loss of or damage to property of such third party, or death or injury to such third party, arising out of a breach by the TSP of any of its obligations under this Agreement, except to the extent that any such claim, action, suit or proceeding has arisen due to a negligent act or omission, breach of this Agreement or non- fulfilment of statutory duty on the part of Nodal Agency; and (b) any and all losses, damages, costs and expenses including legal costs, fines, penalties and interest actually suffered or incurred by the Nodal Agency from third party claims arising by reason of: i. a breach by the TSP of any of its obligations under this Agreement, (provided that this Article 14 shall not apply to such breaches by the TSP, for which specific remedies have been provided for under this Agreement) except to the extent that any such losses, damages, costs and expenses including legal costs, fines, penalties and interest (together to constitute “Indemnifiable Losses”) has arisen due to a negligent act or omission, breach of this Agreement or non-fulfilment of statutory duty on the part of the Nodal Agency, or ii. any of the representations and warranties of the TSP under this Agreement being found to be inaccurate or untrue. 14.1.2 The Nodal Agency shall, in accordance with the Regulations framed by CERC in this regard, indemnify, defend and hold the TSP harmless against: (a) any and all third party claims, actions, suits or proceedings against the TSP, for any loss of or damage to property of such third party, or death or injury to such third party, arising out of any material breach by the Nodal Agency of any of their roles under this Agreement, except to the extent that any such claim, action, suit or proceeding has arisen due to a negligent act or omission, breach of this Agreement or breach of statutory duty on the part of the TSP, its Contractors, servants or agents; and [Insert Name of the SPV] 57 ……2026Transmission Service Agreement (b) any and all losses, damages, costs and expenses including legal costs, fines, penalties and interest (‘Indemnifiable Losses’) actually suffered or incurred by the TSP from third party claims arising by reason of: i. any material breach by the Nodal Agency of any of its roles under this Agreement (provided that, this Article 14 shall not apply to such breaches by the Nodal Agency, for which specific remedies have been provided for under this Agreement), except to the extent that any such Indemnifiable Losses have arisen due to a negligent act or omission, breach of this Agreement or breach of statutory duty on the part of the TSP, its Contractors, servants or agents or ii. any of the representations and warranties of the Nodal Agency under this Agreement being found to be inaccurate or untrue. 14.2 Patent Indemnity: 14.2.1 (a) The TSP shall, subject to the Nodal Agency’s compliance with Article 14.2.1 (b), indemnify and hold harmless the Nodal Agency and its employees and officers from and against any and all suits, actions or administrative proceedings, claims, demands, losses, damages, costs, and expenses of whatsoever nature, including attorney’s fees and expenses, which the Nodal Agency may suffer as a result of any infringement or alleged infringement of any patent, utility model, registered design, trademark, copyright or other intellectual property right registered or otherwise existing at the date of the Agreement by reason of the setting up of the Project by the TSP. Such indemnity shall not cover any use of the Project or any part thereof other than for the purpose indicated by or to be reasonably inferred from the Agreement, any infringement resulting from the misuse of the Project or any part thereof, or any products produced in association or combination with any other equipment, plant or materials not supplied by the TSP, pursuant to the Agreement. (b) If any proceedings are brought or any claim is made against the Nodal Agency arising out of the matters referred to in Article 14.2.1(a), the Nodal Agency shall promptly give the TSP a notice thereof, and the TSP shall at its own expense take necessary steps and attend such proceedings or claim and any negotiations for the settlement of any such proceedings or claim. The TSP shall promptly [Insert Name of the SPV] 58 ……2026Transmission Service Agreement notify the Nodal Agency of all actions taken in such proceedings or claims. (c) If the TSP fails to notify the Nodal Agency within twenty-eight (28) days after receipt of such notice from the Nodal Agency under Article 14.2.1(b) above, that it intends to attend any such proceedings or claim, then the Nodal Agency shall be free to attend the same on their own behalf at the cost of the TSP. Unless the TSP has so failed to notify the Nodal Agency within the twenty eight (28) days period, the Nodal Agency shall make no admission that may be prejudicial to the defence of any such proceedings or claims. (d) The Nodal Agency shall, at the TSP’s request, afford all available assistance to the TSP in attending to such proceedings or claim, and shall be reimbursed by the TSP for all reasonable expenses incurred in so doing. 14.2.2 (a) The Nodal Agency, in accordance with the Regulations framed by CERC in this regard, subject to the TSP’s compliance with Article 14.2.2(b) shall indemnify and hold harmless the TSP and its employees, officers from and against any and all suits, actions or administrative proceedings, claims, demands, losses, damages, costs and expenses of whatsoever nature, including attorney’s fees and expenses, which the TSP may suffer as a result of any infringement or alleged infringement of any patent, utility model, registered design, trademark, copyright or other intellectual property right registered or otherwise existing at the date of the Agreement by reason of the setting up of the Project by the TSP. (b) If any proceedings are brought or any claim is made against the TSP arising out of the matters referred to in Article 14.2.2 (a) the TSP shall promptly give the Nodal Agency a notice thereof, and the Nodal Agency shall at its own expense take necessary steps and attend such proceedings or claim and any negotiations for the settlement of any such proceedings or claim. The Nodal Agency shall promptly notify the TSP of all actions taken in such proceedings or claims. (c) If the Nodal Agency fails to notify the TSP within twenty-eight (28) days after receipt of such notice from the TSP under Article 14.2.2(b) above, that it intends to attend any such proceedings or claim, then the TSP shall be free to attend the same on its own behalf at the cost of the Nodal Agency. Unless the Nodal Agency has so failed to notify the TSP within the twenty (28) days period, the TSP shall make no [Insert Name of the SPV] 59 ……2026Transmission Service Agreement admission that may be prejudicial to the defence of any such proceedings or claim. (d) The TSP shall, at the Nodal Agency request, afford all available assistance to the Nodal Agency in attending to such proceedings or claim, and shall be reimbursed by the Nodal Agency for all reasonable expenses incurred in so doing. 14.3 Monetary Limitation of liability 14.3.1 A Party ("Indemnifying Party") shall be liable to indemnify the other Party ("Indemnified Party") under this Article 14 for any Indemnity Claims made in a Contract Year only up to an amount of Rupees Thirteen Crore Twelve Lakhs Only (Rs. 13.12 Crore). 14.4 Procedure for claiming indemnity 14.4.1 Where the Indemnified Party is entitled to indemnification from the Indemnifying Party pursuant to Articles 14.1 or 14.2 the Indemnified Party shall promptly notify the Indemnifying Party of such claim, proceeding, action or suit referred to in Articles 14.1 or 14.2 in respect of which it is entitled to be indemnified. Such notice shall be given as soon as reasonably practicable after the Indemnified Party becomes aware of such claim, proceeding, action or suit. The Indemnifying Party shall be liable to settle the indemnification claim within thirty (30) days of receipt of the above notice. Provided however that, if: i. the Parties choose to contest, defend or litigate such claim, action, suit or proceedings in accordance with Article 14.4.3 below; and ii. the claim amount is not required to be paid/deposited to such third party pending the resolution of the Dispute, the Indemnifying Party shall become liable to pay the claim amount to the Indemnified Party or to the third party, as the case may be, promptly following the resolution of the Dispute, if such Dispute is not settled in favour of the Indemnified Party. 14.4.2 The Indemnified Party may contest, defend and litigate a claim, action, suit or proceeding for which it is entitled to be indemnified under Articles 14.1 or 14.2 and the Indemnifying Party shall reimburse to the Indemnified Party all reasonable costs and expenses incurred by the Indemnified Party. However, such Indemnified Party shall not settle or compromise such claim, action, suit or proceedings without first getting the consent of the [Insert Name of the SPV] 60 ……2026Transmission Service Agreement Indemnifying Party, which consent shall not be unreasonably withheld or delayed. 14.4.3 An Indemnifying Party may, at its own expense, assume control of the defence of any proceedings brought against the Indemnified Party if it acknowledges its obligation to indemnify such Indemnified Party, gives such Indemnified Party prompt notice of its intention to assume control of the defence, and employs an independent legal counsel at its own cost that is reasonably satisfactory to the Indemnified Party. 14.5 Limitation on Liability 14.5.1 Except as expressly provided in this Agreement, neither the TSP nor the Nodal Agency nor their respective officers, directors, agents, employees or Affiliates (including, officers, directors, agents or employees of such Affiliates), shall be liable or responsible to the other Party or its Affiliates including its officers, directors, agents, employees, successors, insurers or permitted assigns for incidental, indirect or consequential, punitive or exemplary damages, connected with or resulting from performance or non- performance of this Agreement, or anything done in connection herewith, including claims in the nature of lost revenues, income or profits (other than payments expressly required and properly due under this Agreement), any increased expense of, reduction in or loss of transmission capacity or equipment used therefore, irrespective of whether such claims are based upon breach of warranty, tort (including negligence, whether of the Nodal Agency, the TSP or others), strict liability, contract, breach of statutory duty, operation of law or otherwise. 14.5.2 The Nodal Agency shall have no recourse against any officer, director or shareholder of the TSP or any Affiliate of the TSP or any of its officers, directors or shareholders for such claims excluded under this Article. The TSP shall also have no recourse against any officer, director or shareholder of the Nodal Agency, or any Affiliate of the Nodal Agency or any of its officers, directors or shareholders for such claims excluded under this Article. 14.6 Duty to Mitigate The party entitled to the benefit of an indemnity under this Article 14 shall take all reasonable measures to mitigate any loss or damage which has occurred. If the Party fails to take such measures, the other Party’s liabilities shall be correspondingly reduced. [Insert Name of the SPV] 61 ……2026Transmission Service Agreement ARTICLE: 15 15 ASSIGNMENTS AND CHARGES 15.1 Assignments: 15.1.1 This Agreement shall be binding upon, and inure to the benefit of the Parties and their respective successors and permitted assigns. This Agreement shall not be assigned by any Party, except as provided in Article 15.3. 15.2 Permitted Charges: 15.2.1 Neither Party shall create or permit to subsist any encumbrance over all or any of its rights and benefits under this Agreement. 15.2.2 However, the TSP may create any encumbrance over all or part of the receivables, or the Project Assets of the Project in favour of the Lenders or the Lenders’ Representative on their behalf, as security for amounts payable under the Financing Agreements and any other amounts agreed by the Parties. Provided that: i. the Lenders or the Lenders’ Representative on their behalf shall have entered into the Financing Agreements and agreed in writing to the provisions of this Agreement; and ii. any encumbrance granted by the TSP in accordance with this Article 15.2.2 shall contain provisions pursuant to which the Lenders or the Lender’s Representative on their behalf agrees unconditionally with the TSP to release from such encumbrances upon payment by the TSP to the Lenders of all amounts due under the Financing Agreements. 15.2.3 Article 15.2.1 does not apply to: a. liens arising by operation of law (or by an agreement evidencing the same) in the ordinary course of the TSP developing and operating the Project; b. pledges of goods, the related documents of title and / or other related documents, arising or created in the ordinary course of the TSP developing and operating the Project; or [Insert Name of the SPV] 62 ……2026Transmission Service Agreement c. security arising out of retention of title provisions in relation to goods acquired in the ordinary course of the TSP developing and operating the Project. 15.3 Substitution Rights of the Lenders 15.3.1 The TSP would need to operate and maintain the Project under the provisions of this Agreement and cannot assign the Transmission License or transfer the Project or part thereof to any person by sale, lease, exchange or otherwise, without the prior approval of the Nodal Agency. 15.3.2 However, in the case of default by the TSP in debt repayments or in the case of default by the TSP as per Article 13 of this Agreement during the debt repayments, the Commission may, on an application from the Lenders, assign the Transmission License to the nominee of the Lenders subject to the fulfilment of the qualification requirements and provisions of the Central Electricity Regulatory Commission (Procedure, terms and Conditions for grant of Transmission License and other related matters) Regulations, 2006 and as amended from time to time. [Insert Name of the SPV] 63 ……2026Transmission Service Agreement ARTICLE: 16 16 GOVERNING LAW AND DISPUTE RESOLUTION 16.1 Governing Law: This Agreement shall be governed by and construed in accordance with the Laws of India. Any legal proceedings in respect of any matters, claims or disputes under this Agreement shall be under the jurisdiction of appropriate courts in Delhi. 16.2 Amicable Settlement: 16.2.1 Either Party is entitled to raise any claim, dispute or difference of whatever nature arising under, out of or in connection with this Agreement, including its existence or validity or termination or whether during the execution of the Project or after its completion and whether prior to or after the abandonment of the Project or termination or breach of the Agreement by giving a written notice to the other Party, which shall contain: (i) a description of the Dispute; (ii) the grounds for such Dispute; and (iii) all written material in support of its claim. 16.2.2 The other Party shall, within thirty (30) days of issue of notice issued under Article 16.2.1, furnish: (i) counter-claim and defences, if any, regarding the Dispute; and (ii) all written material in support of its defences and counter-claim. 16.2.3 Within thirty (30) days of issue of notice by the Party pursuant to Article 16.2.1, if the other Party does not furnish any counter claim or defense under Article 16.2.2, or thirty (30) days from the date of furnishing counter claims or defence by the other Party, both the Parties to the Dispute shall meet to settle such Dispute amicably. If the Parties fail to resolve the Dispute amicably within thirty (30) days from the later of the dates mentioned in this Article 16.2.3, the Dispute shall be referred for dispute resolution in accordance with Article 16.3. 16.3 Dispute Resolution: All Disputes shall be adjudicated by the Commission. [Insert Name of the SPV] 64 ……2026Transmission Service Agreement 16.4 Parties to Perform Obligations: Notwithstanding the existence of any Dispute and difference referred to the Commission as provided in Article 16.3 and save as the Commission may otherwise direct by a final or interim order, the Parties hereto shall continue to perform their respective obligations/ roles (which are not in dispute) under this Agreement. [Insert Name of the SPV] 65 ……2026Transmission Service Agreement ARTICLE: 17 17 REPRESENTATION AND WARRANTIES 17.1 Representation and warranties of the Nodal Agency 17.1.1 The Nodal Agency hereby represents and warrants to and agrees with the TSP as follows and acknowledges and confirms that the TSP is relying on such representations and warranties in connection with the transactions described in this Agreement: a. It has all requisite powers and authority to execute and consummate this Agreement; b. This Agreement is enforceable against the Nodal Agency in accordance with its terms; c. The consummation of the transactions contemplated by this Agreement on the part of Nodal Agency will not violate any provision of nor constitute a default under, nor give rise to a power to cancel any charter, mortgage, deed of trust or lien, lease, agreement, license, permit, evidence of indebtedness, restriction, or other contract to which the Nodal Agency is a Party or to which the Nodal Agency is bound, which violation, default or power has not been waived; 17.2 Representation and Warranties of the TSP: 17.2.1 The TSP hereby represents and warrants to and agrees with the Nodal Agency as follows and acknowledges and confirms that the Nodal Agency is relying on such representations and warranties in connection with the transactions described in this Agreement: a. It has all requisite powers and has been duly authorized to execute and consummate this Agreement; b. This Agreement is enforceable against it, in accordance with its terms; c. The consummation of the transactions contemplated by this Agreement on the part of the TSP will not violate any provision of nor constitute a default under, nor give rise to a power to cancel any charter, mortgage, deed of trust or lien, lease, agreement, license, permit, evidence of indebtedness, restriction, or other contract to which the TSP is a Party or to which the TSP is bound which violation, default or power has not been waived; [Insert Name of the SPV] 66 ……2026Transmission Service Agreement d. The TSP is not insolvent and no insolvency proceedings have been instituted, nor threatened or pending by or against the TSP; e. There are no actions, suits, claims, proceedings or investigations pending or, to the best of the TSP’s knowledge, threatened in writing against the TSP at law, in equity, or otherwise, and whether civil or criminal in nature, before or by, any court, commission, arbitrator or governmental agency or authority, and there are no outstanding judgments, decrees or orders of any such courts, commission, arbitrator or governmental agencies or authorities, which materially adversely affect its ability to execute the Project or to comply with its obligations under this Agreement. 17.2.2 The TSP makes all the representations and warranties above to be valid as on the Effective Date of this Agreement. [Insert Name of the SPV] 67 ……2026Transmission Service Agreement ARTICLE: 18 18 INDEPENDENT ENGINEER 18.1 Appointment of Independent Engineer The Nodal Agency shall appoint an agency/ company as Independent Engineer as per framework provided in the Guidelines for Encouraging Competition in Development of Transmission Projects for selection of Independent Engineer. 18.2 Roles and functions of Independent Engineer The role and functions of the Independent Engineer shall include the following: a. Progress Monitoring as required under this Agreement; b. Ensuring Quality as required under this Agreement; c. determining, as required under the Agreement, the costs of any works or services and/or their reasonableness during construction phase; d. determining, as required under the Agreement, the period or any extension thereof, for performing any duty or obligation during construction phase; e. determining, as required under the Agreement, the valuation of the Project Assets. f. Assisting the Parties in resolution of Disputes and g. Undertaking all other duties and functions in accordance with the Agreement. 18.3 Remuneration of Independent Engineer The fee and charges of the Independent Engineer shall be paid by the Nodal Agency as per terms & conditions of appointment. 18.4 Termination of appointment 18.4.1 The Nodal Agency may, in its discretion, terminate the appointment of the Independent Engineer at any time, but only after appointment of another Independent Engineer. [Insert Name of the SPV] 68 ……2026Transmission Service Agreement 18.4.2 If the TSP has reason to believe that the Independent Engineer is not discharging its duties and functions in a fair, efficient and diligent manner, it may make a written representation to the Nodal Agency and seek termination of the appointment of the Independent Engineer. Upon receipt of such representation, the Nodal Agency shall hold a tripartite meeting with the TSP and Independent Engineer for an amicable resolution, and the decision of Nodal agency is final. In the event that the appointment of the Independent Engineer is terminated hereunder, the Nodal Agency shall appoint forthwith another Independent Engineer. 18.5 Authorised signatories The Nodal Agency shall require the Independent Engineer to designate and notify to the Nodal Agency up to 2 (two) persons employed in its firm to sign for and on behalf of the Independent Engineer, and any communication or document required to be signed by the Independent Engineer shall be valid and effective only if signed by any of the designated persons; provided that the Independent Engineer may, by notice in writing, substitute any of the designated persons by any of its employees. [Insert Name of the SPV] 69 ……2026Transmission Service Agreement ARTICLE: 19 19 MISCELLANEOUS PROVISIONS 19.1 Equity Lock-in Commitment: 19.1.1 The aggregate equity share holding of the Selected Bidder in the issued and paid-up equity share capital of ................................[Insert Name of the SPV] shall not be less than Fifty one percent (51%) up to a period of one (1) year after COD of the Project. Provided that, in case the Lead Member or Bidding Company is holding equity through Affiliate/s, Ultimate Parent Company or Parent Company, such restriction as specified above shall apply to such entities. Provided further, that in case the Selected Bidder is a Bidding Consortium, the Lead Member shall continue to hold equity of at least twenty six percent (26%) upto a period of one (1) year after COD of the Project and any Member of such Bidding Consortium shall be allowed to divest its equity as long as the other remaining Members (which shall always include the Lead Member) hold the minimum equity specified above. 19.1.2 If equity is held by the Affiliates, Parent Company or Ultimate Parent Company of the Selected Bidder, then, subject to the second proviso to Article 19.1.1, such Affiliate, Parent Company or Ultimate Parent Company shall be eligible to transfer its shareholding in ................................[Insert Name of the SPV] to another Affiliate or to the Parent Company / Ultimate Parent Company of the Selected Bidder. If any such shareholding entity, qualifying as an Affiliate / Parent Company / Ultimate Parent Company, is likely to cease to meet the criteria to qualify as an Affiliate / Parent Company / Ultimate Parent Company, the shares held by such entity shall be transferred to another Affiliate / Parent Company / Ultimate Parent Company of the Selected Bidder. 19.1.3 Subject to Article 19.1.1, all transfer(s) of shareholding of ................................[Insert Name of the SPV] by any of the entities referred to in Article 19.1.1 and 19.1.2 above, shall be after prior written intimation to the Nodal Agency. 19.1.4 For computation of effective Equity holding, the Equity holding of the Selected Bidder or its Ultimate Parent Company in such Affiliate(s) or Parent Company and the equity holding of such Affiliate(s) or Ultimate Parent Company in ................................[Insert Name of the SPV] shall be computed in accordance with the example given below: [Insert Name of the SPV] 70 ……2026Transmission Service Agreement If the Parent Company or the Ultimate Parent Company of the Selected Bidder A directly holds thirty percent (30%) of the equity in ................................[Insert Name of the SPV] then holding of Selected Bidder A in ................................[Insert Name of the SPV] shall be thirty percent (30%); If Selected Bidder A holds thirty percent (30%) equity of the Affiliate and the Affiliate holds fifty percent (50%) equity in ................................[Insert Name of the SPV], then, for the purposes of ascertaining the minimum equity/equity lock-in requirements specified above, the effective holding of Bidder A in ................................[Insert Name of the SPV] shall be fifteen percent (15%), (i.e., 30% x 50%) 19.1.5 The provisions as contained in this Article 19.1 shall override the terms of the consortium agreement submitted as part of the Bid. 19.1.6 The TSP shall be responsible to report to Nodal Agency, within thirty (30) days from the occurrence of any event that would result in any change in its equity holding structure from that which existed as on the date of signing of the Share Purchase Agreement. In such cases, the Nodal Agency would reserve the right to ascertain the equity holding structure and to call for all such required documents / information / clarifications as may be required. 19.2 Commitment of maintaining Qualification Requirement 19.2.1 The Selected Bidder will be required to continue to maintain compliance with the Qualification Requirements, as stipulated in RFP Document, till the COD of the Project. Where the Technically Evaluated Entity and/or the Financially Evaluated Entity is not the Bidding Company or a Member in a Bidding Consortium, as the case may be, the Bidding Company or Member shall continue to be an Affiliate of the Technically Evaluated Entity and/or Financially Evaluated Entity till the COD of the Project. 19.2.2 Failure to comply with the aforesaid provisions shall be dealt in the same manner as TSP’s Event of Default as under Article 13 of this Agreement. 19.3 Language: 19.3.1 All agreements, correspondence and communications between the Parties relating to this Agreement and all other documentation to be prepared and supplied under the Agreement shall be written in English, and the Agreement shall be construed and interpreted in accordance with English language. 19.3.2 If any of the agreements, correspondence, communications or documents [Insert Name of the SPV] 71 ……2026Transmission Service Agreement are prepared in any language other than English, the English translation of such agreements, correspondence, communications or documents shall prevail in matters of interpretation. 19.4 Affirmation The TSP and the Nodal Agency, each affirm that: 1. neither it nor its respective directors, employees, or agents has paid or undertaken to pay or shall in the future pay any unlawful commission, bribe, pay-off or kick-back; and 2. it has not in any other manner paid any sums, whether in Indian currency or foreign currency and whether in India or abroad to the other Party to procure this Agreement, and the TSP and the Nodal Agency hereby undertake not to engage in any similar acts during the Term of Agreement. 19.5 Severability The invalidity or enforceability, for any reason, of any part of this Agreement shall not prejudice or affect the validity or enforceability of the remainder of this Agreement, unless the part held invalid or unenforceable is fundamental to this Agreement. 19.6 Counterparts This Agreement may be executed in one or more counterparts, each of which shall be deemed an original and all of which collectively shall be deemed one and the same Agreement. 19.7 Breach of Obligations/ Roles The Parties acknowledge that a breach of any of the obligations/ roles contained herein would result in injuries. The Parties further acknowledge that the amount of the liquidated damages or the method of calculating the liquidated damages specified in this Agreement is a genuine and reasonable pre-estimate of the damages that may be suffered by the non- defaulting Party in each case specified under this Agreement. 19.8 Restriction of Shareholders / Owners Liability 19.8.1 Parties expressly agree and acknowledge that none of the shareholders of the Parties hereto shall be liable to the other Parties for any of the contractual obligations of the concerned Party under this Agreement. 19.8.2 Further, the financial liabilities of the shareholder(s) of each Party to this [Insert Name of the SPV] 72 ……2026Transmission Service Agreement Agreement shall be restricted to the extent provided in the Indian Companies Act, 1956 / Companies Act, 2013 (as the case may be). 19.9 Taxes and Duties: 19.9.1 The TSP shall bear and promptly pay all statutory taxes, duties, levies and cess, assessed/levied on the TSP, its Contractors or their employees that are required to be paid by the TSP as per the Law in relation to the execution of the Project and for providing Transmission Service as per the terms of this Agreement. 19.9.2 The Nodal Agency shall be indemnified and held harmless by the TSP against any claims that may be made against the Nodal Agency in relation to the matters set out in Article 19.9.1. 19.9.3 The Nodal Agency shall not be liable for any payment of, taxes, duties, levies, cess whatsoever for discharging any obligation of the TSP by the Nodal Agency on behalf of TSP or its personnel, provided the TSP has consented in writing to the Nodal Agency for such work, for which consent shall not be unreasonably withheld. 19.10 No Consequential or Indirect Losses The liability of the TSP shall be limited to that explicitly provided in this Agreement. Provided that, notwithstanding anything contained in this Agreement, under no event shall the Nodal Agency or the TSP claim from one another any indirect or consequential losses or damages. 19.11 Discretion: Except where this Agreement expressly requires a Party to act fairly or reasonably, a Party may exercise any discretion given to it under this Agreement in any way it deems fit. 19.12 Confidentiality 19.12.1 The Parties undertake to hold in confidence this Agreement and RFP Project Documents and not to disclose the terms and conditions of the transaction contemplated hereby to third parties, except: (a) to their professional advisors; (b) to their officers, contractors, employees, agents or representatives, financiers, who need to have access to such information for the [Insert Name of the SPV] 73 ……2026Transmission Service Agreement proper performance of their activities; or (c) disclosures required under Law, without the prior written consent of the other Parties. Provided that, the TSP agrees and acknowledges that the Nodal Agency, may, at any time, disclose the terms and conditions of the Agreement and the RFP Project Documents to any person, to the extent stipulated under the Law and the Competitive Bidding Guidelines. 19.13 Order of priority in application: Save as provided in Article 2.5, in case of inconsistencies between the terms and conditions stipulated in Transmission License issued by the Commission to the TSP, agreement(s) executed between the Parties, applicable Law including rules and regulations framed thereunder, the order of priority as between them shall be the order in which they are placed below:  terms and conditions of Transmission License;  applicable Law, rules and regulations framed thereunder;  this Agreement;  Agreement(s), if any, under Sharing Regulations. 19.14 Independent Entity: 19.14.1 The TSP shall be an independent entity performing its obligations pursuant to the Agreement. 19.14.2 Subject to the provisions of the Agreement, the TSP shall be solely responsible for the manner in which its obligations under this Agreement are to be performed. All employees and representatives of the TSP or Contractors engaged by the TSP in connection with the performance of the Agreement shall be under the complete control of the TSP and shall not be deemed to be employees, representatives, Contractors of the Nodal Agency and nothing contained in the Agreement or in any agreement or contract awarded by the TSP shall be construed to create any contractual relationship between any such employees, representatives or Contractors and the Nodal Agency. 19.15 Amendments: 19.15.1 This Agreement may only be amended or supplemented by a written [Insert Name of the SPV] 74 ……2026Transmission Service Agreement agreement between the Parties. 19.16 Waiver: 19.16.1 No waiver by either Party of any default or breach by the other Party in the performance of any of the provisions of this Agreement shall be effective unless in writing duly executed by an authorised representative of such Party. 19.16.2 Neither the failure by either Party to insist on any occasion upon the performance of the terms, conditions and provisions of this Agreement nor time or other indulgence granted by one Party to the other Parties shall act as a waiver of such breach or acceptance of any variation or the relinquishment of any such right or any other right under this Agreement, which shall remain in full force and effect. 19.17 Relationship of the Parties: This Agreement shall not be interpreted or construed to create an association, joint venture, or partnership or agency or any such other relationship between the Parties or to impose any partnership obligation or liability upon either Party and neither Party shall have any right, power or authority to enter into any agreement or undertaking for, or act on behalf of, or to act as or be an agent or representative of, or to otherwise bind, the other Party. 19.18 Entirety: 19.18.1 This Agreement along with its sections, schedules and appendices is intended by the Parties as the final expression of their agreement and is intended also as a complete and exclusive statement of the terms of their agreement. 19.18.2 Except as provided in this Agreement, all prior written or oral understandings, offers or other communications of every kind pertaining to this Agreement or the provision of Transmission Service under this Agreement to the Nodal Agency by the TSP shall stand superseded and abrogated. 19.19 Notices: 19.19.1 All notices or other communications which are required to be given under this Agreement shall be in writing and in the English language 19.19.2 If to the TSP, all notices or communications must be delivered personally or by registered post or facsimile or any other mode duly acknowledged to [Insert Name of the SPV] 75 ……2026Transmission Service Agreement the addressee below: Address : Attention : Email : Fax. No. : Telephone No. : 19.19.3 If to the Nodal Agency, all notices or communications must be delivered personally or by registered post or facsimile or any other mode duly acknowledged to the addresses below: (i) …………… [Insert Name of the Nodal Agency] Address : Attention Email : Fax. No. : Telephone No. : 19.19.4 All notices or communications given by facsimile shall be confirmed by sending a copy of the same via post office in an envelope properly addressed to the appropriate Party for delivery by registered mail. All notices shall be deemed validly delivered upon receipt evidenced by an acknowledgement of the recipient, unless the Party delivering the notice can prove in case of delivery through the registered post that the recipient refused to acknowledge the receipt of the notice despite efforts of the postal authorities. 19.19.5 Any Party may by notice of at least fifteen (15) days to the other Party change the address and/or addresses to which such notices and communications to it are to be delivered or mailed. 19.20 Fraudulent and Corrupt Practices 19.20.1 The TSP and its respective officers, employees, agents and advisers shall observe the highest standard of ethics during the subsistence of this Agreement. Notwithstanding anything to the contrary contained in the Agreement, the Nodal Agency may terminate the Agreement without being liable in any manner whatsoever to the TSP, if it determines that the TSP has, directly or indirectly or through an agent, engaged in corrupt practice, fraudulent practice, coercive practice, undesirable practice or restrictive practice in the Bid process. In such an event, the Nodal Agency shall forfeit the Contract Performance Guarantee of the TSP, without prejudice to any other right or remedy that may be available to the Nodal Agency hereunder [Insert Name of the SPV] 76 ……2026Transmission Service Agreement or subsistence otherwise. 19.20.2 Without prejudice to the rights of the Nodal Agency under Clause 19.20.1 hereinabove and the rights and remedies which the Nodal Agency may have under this Agreement, if a TSP is found by the Nodal Agency to have directly or indirectly or through an agent, engaged or indulged in any corrupt practice, fraudulent practice, coercive practice, undesirable practice or restrictive practice during the Bid process, or after the issue of Letter of Intent (hereinafter referred to as LoI) or after the execution of the agreement(s) required under Sharing Regulations, the Nodal Agency may terminate the Agreement without being liable in any manner whatsoever to the TSP. Further, the TSP & its Affiliates shall not be eligible to participate in any tender or RFP issued by any BPC for an indefinite period from the date such TSP is found by the Nodal Agency to have directly or indirectly or through an agent, engaged or indulged in any corrupt practice, fraudulent practice, coercive practice, undesirable practice or restrictive practices, as the case may be. 19.20.3 For the purposes of this Clause 19.20, the following terms shall have the meaning hereinafter respectively assigned to them: (a) “corrupt practice” means (i) the offering, giving, receiving, or soliciting, directly or indirectly, of anything of value to influence the actions of any person connected with the Bid process (for avoidance of doubt, offering of employment to or employing or engaging in any manner whatsoever, directly or indirectly, any official of the BPC who is or has been associated or dealt in any manner, directly or indirectly with the Bid process or the LoI or has dealt with matters concerning the RFP Project Documents or arising there from, before or after the execution thereof, at any time prior to the expiry of one year from the date such official resigns or retires from or otherwise ceases to be in the service of the BPC, shall be deemed to constitute influencing the actions of a person connected with the Bid Process); or (ii) engaging in any manner whatsoever, whether during the Bid Process or after the issue of the LoI or after the execution of the RFP Project Documents, as the case may be, any person in respect of any matter relating to the Project or the LoI or the RFP Project Documents, who at any time has been or is a legal, financial or technical adviser of the BPC in relation to any matter concerning the Project; (b) “fraudulent practice” means a misrepresentation or omission of facts or suppression of facts or disclosure of incomplete facts, in order to influence the Bid process; [Insert Name of the SPV] 77 ……2026Transmission Service Agreement (c) “coercive practice” means impairing or harming, or threatening to impair or harm, directly or indirectly, any person or property to influence any person’s participation or action in the Bid process; (d) “undesirable practice” means (i) establishing contact with any person connected with or employed or engaged by the BPC with the objective of canvassing, lobbying or in any manner influencing or attempting to influence the Bid process; or (ii) having a Conflict of Interest; and (e) “restrictive practice” means forming a cartel or arriving at any understanding or arrangement among Bidders with the objective of restricting or manipulating a full and fair competition in the Bid process; 19.21 Compliance with Law: Despite anything contained in this Agreement but without prejudice to Article 12, if any provision of this Agreement shall be in deviation or inconsistent with or repugnant to the provisions contained in the Electricity Act, 2003, or any rules and regulations made there under, such provision shall be deemed to be amended to the extent required to bring it into compliance with the aforesaid relevant provisions as amended from time to time. IN WITNESS WHEREOF, THE PARTIES HAVE CAUSED THIS AGREEMENT TO BE EXECUTED BY THEIR DULY AUTHORISED REPRESENTATIVES AS OF THE DATE AND PLACE SET FORTH ABOVE. 1. For and on behalf of TSP …………………………….. [Signature, Name, Designation and Address] 2. For and on behalf of .........................[Insert name of the Nodal Agency] …………………………….. [Signature, Name, Designation and Address] [Insert Name of the SPV] 78 ……2026Transmission Service Agreement WITNESSES: 1. For and on behalf of : BPC …………………………… [Signature] ............................................................... [Insert, Name, Designation and Address of the Witness] 2. For and on behalf of : Nodal Agency …………………………… [Signature] ........................................................... [Insert Name, Designation and Address of the Witness] [Insert Name of the SPV] 79 ……2026Transmission Service Agreement SCHEDULES [Insert Name of the SPV] 80 ……2026Transmission Service Agreement Schedule: 1 Project Description and Scope of Project Scope of the Project: Scheduled COD Sl. Scope of the Transmission Scheme in months from No. Effective Date Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) GIS substation with 1x330 MVAr (765 kV) bus reactor with space provision for establishment of 220 kV switchyard  765/400 kV, 1500 MVA, ICTs – 4 Nos. (13x500 MVA incl. 1 spare unit)  765 kV ICT bay – 4 Nos.  400 kV ICT bay – 4 Nos.  765 kV line bays – 2 Nos. (at Pendurthi (Vizag) GIS for termination of Pendurthi (Vizag) – Srikakulam 765 kV D/c line)  765 kV line bays – 2 Nos. with provision of SLR (at Pendurthi (Vizag) GIS for termination of Khammam-II – Pendurthi (Vizag) –765 kV D/c 1. line) 30 Months  765 kV, 330 MVAr Bus Reactors – 1 No. (4x110 MVAr inc. 1 switchable spare unit for both bus reactor and line reactor)  765 kV Bus Reactor bays – 1 No.  400 kV line bays – 4 Nos. (at Pendurthi (Vizag) GIS for termination of LILO of Kalpakka – Maradam 400 kV (quad) D/c line at Pendurthi) Future Space Provisions:  765/400 kV, 1500 MVA, ICTs – 2 Nos.  765 kV ICT bays – 2 Nos.  400 kV ICT bays – 2 Nos.  765 kV line bays – 8 Nos. (with provision for SLR) [Insert Name of the SPV] 81 ……2026Transmission Service Agreement  400 kV line bays – 12 Nos. (with provision for SLR)  400 kV Bus Sectionalizer : 1 set Future Space Provisions for 220kV switchyard:  400/220 kV, 500 MVA, ICTs – 10 Nos.  400 kV ICT bays – 10 Nos.  220 kV ICT bays – 10 Nos.  220 kV line bays – 16 Nos.  220 kV Bus Sectionalizer: 3 set  220 kV Bus Coupler (BC) Bay – 4 Nos.  220 kV Transfer Bus Coupler (TBC) Bay – 4 Nos. + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS with control switching arrangement for proposed 1x330 MVAr bus reactor Space provision for 2nd + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS 2.  + 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) GIS with control switching arrangement for proposed 1x330 MVAr bus reactor – 1 set  400 kV bay – 1 No. Pendurthi (Vizag) – Srikakulam 765 kV D/c line with 330 MVAr SLR (convertible) at Srikakulam end on both circuits  765 kV line along with SLR GIS bays at Srikakulam - The D/c line to be terminated in 3. the future line bays with SLR proposed under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid”  765 kV, 330 MVAr SLR at Srikakulam – 2 Nos. (7x110 MVAr switchable units inc. 1 switchable spare unit) [Insert Name of the SPV] 82 ……2026Transmission Service Agreement LILO of Kalpakka – Maradam 400 kV (quad) D/c 4. line at Pendurthi Establishment of 3x1500 MVA, 765/400 kV Khammam-II substation with 1x330 MVAr (765 kV) bus reactor with space provision for establishment of 220 kV switchyard  765/400 kV, 1500 MVA, ICTs – 3 Nos. (10x500 MVA incl. 1 spare unit)  765 kV ICT bay – 3 Nos.  400 kV ICT bay – 3 Nos.  765 kV line bays – 4 Nos. (at Khammam-II for termination of Khammam-II – Pendurthi and Khammam-II – Warangal New 765 kV D/c lines)  765 kV, 330 MVAr Bus Reactors – 1 No. (4x110 MVAr inc. 1 switchable spare unit for both bus reactor and line reactor)  765 kV Bus Reactor bays – 1 No.  400 kV line bays – 2 Nos. (at Khammam-II for termination of Khammam-II – Khammam 5. (existing) 400 kV (quad) D/c line) Future Space Provisions:  765/400 kV, 1500 MVA, ICTs – 3 Nos.  765 kV ICT bays – 3 Nos.  400 kV ICT bays – 3 Nos.  765 kV line bays – 8 Nos. (with provision for SLR)  400 kV line bays – 10 Nos. (with provision for SLR)  400 kV Bus Sectionalizer: 1 set Future Space Provisions for 220kV switchyard:  400/220 kV, 500 MVA, ICTs – 10 Nos.  400 kV ICT bays – 10 Nos.  220 kV ICT bays – 10 Nos.  220 kV line bays – 16 Nos. [Insert Name of the SPV] 83 ……2026Transmission Service Agreement  220 kV Bus Sectionalizer: 3 set  220 kV Bus Coupler (BC) Bay – 4 Nos.  220 kV Transfer Bus Coupler (TBC) Bay – 4 Nos Khammam-II – Warangal New 765 kV D/c line 6.  765 kV line bays – 2 Nos. (at Warangal New) Khammam-II – Pendurthi (Vizag) 765 kV D/c line with 330 MVAr SLR (convertible) at both ends on both circuits  765 kV, 330 MVAr SLR at Pendurthi (Vizag) – 2 Nos. (6x110 MVAr switchable units) 7.  Switching Equipment for 765 kV SLR at Pendurthi (Vizag) GIS – 2 Nos  765 kV, 330 MVAr SLR at Khammam-II – 2 Nos. (6x110 MVAr switchable units)  Switching Equipment for 765 kV SLR at Khammam-II PS – 2 Nos Khammam-II – Khammam (existing) 400 kV (quad) D/c line 8.  400kV line bays – 2 Nos. (at Khammam (existing)) Note: i. Bay(s) required for completion of diameter (GIS) in one-and-half breaker scheme shall also be executed by the TSP. ii. POWERGRID to provide space (free of cost) for 765 kV line along with SLR GIS bays at Srikakulam - The D/c line to be terminated in the future line bays with SLR proposed under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid” iii. POWERGRID to provide space (free of cost) for 2 Nos. of 400 kV line bays at Khammam for termination of Khammam-II – Khammam (existing) 400 kV (quad) D/c line iv. TSP of Warangal New S/s (Adani) to provide space (free of cost) for 2 Nos. of 765 kV line bays with provision of SLR at Warangal New S/s for termination of Khammam- II – Warangal New 765 kV D/c line [Insert Name of the SPV] 84 ……2026Transmission Service Agreement Project Description As per the Communication from MNRE, about 5000 MW demand at Vizag area and 6000 MW at Kakinada area has been envisaged for the Green Hydrogen / Green Ammonia projects. The transmission system for proposed Green Hydrogen / Green Ammonia projects in Kakinada area, Andhra Pradesh (Phase- I) is presently under bidding. Further, a comprehensive Transmission system for Green Hydrogen / Green Ammonia projects at Kakinada (Ph-II) and Pendurthi have been identified. Further, a number of datacentre loads are envisaged near Pendurthi / Vizag area and applications have already been received from certain developers at Pendurthi by APTRANSCO for which the subject transmission system shall be used. The Transmission System was discussed and agreed in the 38th CMETS-SR held on 02.06.2025. The scheme was further discussed and agreed in the 55th SRPC meeting held on 26.07.2025. Further, CTU have received GNA application for 2500 MW as bulk consumer from different Green Hydrogen / Green Ammonia project developer. The present transmission scheme shall facilitate integration and supply of power to Green Hydrogen / Green Ammonia projects for meeting their demand for about 4500 MW. The National Committee on Transmission in its 32nd meeting held on 12.08.2025 has recommended the implementation of the subject transmission scheme through TBCB route and has identified the RECPDCL as BPC for bidding of the transmission scheme. Ministry of Power vide Gazette notification dated 26.12.2025 has notified the transmission scheme for implementation through TBCB route. [Insert Name of the SPV] 85 ……2026Transmission Service Agreement SPECIFIC TECHNICAL REQUIREMENTS FOR TRANSMISSION LINE The design, routing and construction of transmission lines shall be in accordance with Chapter V, Part A of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Other CEA Regulations/ guidelines as amended up to date and Ministry of Power (MoP) guidelines, as applicable, shall also be followed. A.1.0 Selection of tower type shall be made as per CEA Regulations, however, in case lattice type towers are used, the following shall also be applicable: A.2.0 Steel section of grade E 250 and/or grade E 350 as per IS 2062, only are permitted for use in towers, extensions, gantry structures and stub setting templates. For towers in snowbound areas, steel sections shall conform to Grade-C of IS-2062. A.3.0 Towers shall be designed as per IS-802:2015, however the drag coefficient of the tower shall be as follows: - Solidity Ratio Drag Coefficient Up to 0.05 3.6 0.1 3.4 0.2 2.9 0.3 2.5 0.4 2.2 0.5 and above 2.0 A.4.0 Transmission Service Provider (TSP) shall adopt any additional loading/ design criteria for ensuring reliability of the line, if so desired and /or deemed necessary. A.5.0 Transmission line shall be designed considering wind zones as specified in wind map given in National Building Code 2016, Vol.1. The developer shall also make his own assessment of local wind conditions and frequent occurrences of High Intensity Winds (HIW) due to thunderstorms, dust storms, downburst etc. along the line route and wherever required, higher wind zone than that given in wind map shall be considered for tower design for ensuring reliability of line. Further, for transmission line sections passing within a distance of 50 km from the boundary of two wind zones, higher of the two wind zones shall be considered for design of towers located in such sections. [Insert Name of the SPV] 86 ……2026Transmission Service Agreement A.6.0 Selection of reliability level for design of tower shall be as per CEA Regulation (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. A.7.0 a) In case of construction of transmission line of Voltage level of 400 kV and above, under crossing of the existing transmission line shall not be allowed. In the case where it is inevitable to under-cross the existing transmission line then TSP shall seek prior approval from Chief Electrical Inspector, CEA with detailed study ensuring that all statutory electrical clearances and Electric Field limit of 10 kV/m at 1 m and 1.8 m from ground level is not violated. b) For power line crossing of 400 kV or above voltage level, large angle and dead end towers (i.e. D/DD/QD) shall be used on either side of power line crossing. c) For power line crossing of 132 kV and 220 kV (or 230 kV) voltage level, angle towers (B/C/D/DB/DC/DD/ QB/QC/QD) shall be used on either side of power line crossing depending upon the merit of the prevailing site condition and line deviation requirement. d) For power line crossing of 66 kV and below voltage level, suspension/tension towers shall be provided on either side of power line crossing depending upon the merit of the prevailing site condition and line deviation requirement. e) For crossing of railway tracks, national highways and state highways, the rules/ regulations of appropriate authorities shall be followed. A.8.0 The relevant conductor configuration shall be as follows: - A. For 765 kV lines under the scheme: i) Pendurthi (Vizag) – Srikakulam 765 kV D/c line ii) Khammam-II – Warangal New 765 kV D/c line iii) Khammam-II – Pendurthi (Vizag) 765 kV D/c line Type of conductor: ACSR / AAAC / AL59 [Insert Name of the SPV] 87 ……2026Transmission Service Agreement Basic Parameters: Transmission ACSR Equivalent Equivalent Sub- line AAAC minimum size conductor Conductor conductor of AL59 Spacing specified based on conductor 53.5% based on 59% conductivity of conductivity of Al Alloy AL Alloy* 765 kV D/C Zebra : Stranding Stranding (Hexa Bundle) Stranding details: details: Transmission 54/3.18 mm-Al 61/3.19 mm, 61/3.08 mm, Lines + 7/3.18 mm- Steel, 428.9 487.5 mm2 454 mm2 457 mm mm2, Aluminium alloy Aluminium alloy Aluminium area area area, 28.71 mm 27.72 mm diameter diameter 28.62 mm diameter Maximum DC Maximum DC Resistance at Resistance at Maximum DC 20°C (Ω/km): 20°C (Ω/km): Resistance at 0.06815 0.0653 20°C (Ω/km): 0.0677 Minimum UTS: Minimum UTS: 135.6 kN 108 kN Minimum UTS: 131.44 kN B. For 400 kV lines under the scheme: i) Khammam-II – Khammam (existing) 400 kV (quad) D/c line ii) LILO of Kalpakka – Maradam 400 kV (quad) D/c line at Pendurthi Type of conductor: ACSR / AAAC / AL59 Basic Parameters: [Insert Name of the SPV] 88 ……2026Transmission Service Agreement Transmission ACSR Equivalent Equivalent Sub- line AAAC minimum size conductor Conductor conductor of AL59 Spacing specified based on 53% conductor conductivity of based on 59% Al Alloy conductivity of AL Alloy* 400 kV D/C Moose: Stranding Stranding Stranding details: details: (Quad Bundle) 54/3.53mm-Al + 61/3.55mm 61/3.31mm Transmission 7/3.53 mm- Steel, Lines 31.95mm 29.79 mm 31.77 mm diameter; diameter; diameter 457 mm 525 mm2 604 mm2 528.5 mm2, Aluminium alloy Aluminium area, Aluminium alloy area area Maximum DC Maximum DC Maximum DC Resistance at Resistance at Resistance at 20°C (Ω/km): 20°C (Ω/km): 20°C (Ω/km): 0.0566 0.05506 0.0549 Minimum UTS: Minimum UTS: Minimum UTS: 124.70 kN 159.80 kN 159.60 kN Note: 1. *To select any size above the minimum, the sizes mentioned in the Indian standard IS-398 (part-6) shall be followed. 2. The transmission lines shall have to be designed for a maximum operating conductor temperature of 85 OC. A.9.0 The required phase to phase spacing and horizontal spacing for 765 kV and 400 kV line(s) shall be governed by the tower design as well as minimum live metal clearances for 765 kV and 400 kV voltage level under different insulator swing angles. However, the phase to phase spacing for 765 kV line shall not be less than 15 m and for 400 kV line shall not be less than 8 m. [Insert Name of the SPV] 89 ……2026Transmission Service Agreement A.10.0 All electrical clearances including minimum live metal clearance, ground clearance and minimum mid span separation between earth wire and conductor as given below shall be considered: I. Minimum live metal clearances for 765 kV line: (i) Under stationary conditions From tower body: For 765 kV D/C: 6.1 m For 765 kV S/C: 5.6 m (ii) Under swing conditions Wind Pressure Minimum Electrical Condition Clearance a) Swing angle (25º) 4.4 m b) Swing angle (55º) 1.3 m (iii) Minimum ground clearance for 765 kV line: 18 m (iv) Minimum mid span separation between earth-wire and conductor for 765 kV line: 9.0 m II. Minimum live metal clearances for 400 kV line: (i) Under stationary conditions From tower body: 3.05 m (ii) Under swing conditions Wind pressure Minimum electrical Condition clearance a) Swing angle (22º) 3.05 m b) Swing angle (44º) 1.86 m (iii) Minimum ground clearance for 400 kV line: 8.84 m (iv) Minimum mid span separation between earth-wire and conductor for 400 kV line: 9.0 m A.11.0 Shielding angle shall not exceed 10 deg for 765 kV D/C and 20 deg for 400 kV D/C Line transmission line. A.12.0 The Fault current for design of line shall be 50 kA for 1 sec for 765 kV and 63 kA for 1 sec for 400 kV. A.13.0 In case of 400 kV and above voltage class lines, at least one out of two earth wires shall be OPGW and second earth wire, if not OPGW, shall be either of Galvanized Stranded Steel (GSS) or Aluminum Alloy Conductor Steel Reinforced (AACSR) conductor type or any other suitable conductor type depending upon span length and other technical consideration. [Insert Name of the SPV] 90 ……2026Transmission Service Agreement A.14.0 Each tower shall be earthed such that tower footing impedance does not exceed 10 ohms. Pipe type or Counterpoise type earthing shall be provided in accordance with relevant IS. Additional earthing shall be provided on every 7 to 8 km distance for direct earthing of both shield wires. If site condition demands, multiple earthing or use of earthing enhancement compound shall be used. A.15.0 Pile type foundation shall be used for towers located in river or creek bed or on bank of river having scourable strata or in areas where river flow or change in river course is anticipated, based on detailed soil investigation and previous years’ maximum flood discharge of the river, maximum velocity of water, highest flood level, scour depth and anticipated change in course of river based on river morphology data of at least past 20 years to ensure availability and reliability of the transmission line. A.16.0 Transmission line route shall be finalized, in consultation with appropriate authorities so as to avoid the habitant zones of endangered species and other protected species. Bird diverters, wherever required, shall be provided on the transmission line. In order to optimize the route, use of GATISHAKTI platform shall also be made. A.17.0 Wherever, transmission lines are passing through cyclone prone areas i.e., areas up to 60 km from coast following shall also be applicable: a) Terrain category-I, with terrain roughness factor (K2) of 1.08 shall be considered for tower design for exposed open terrain with few or no obstruction, which also includes open sea coasts, open stretch of water, desert and flat treeless plains. b) Importance factor for cyclonic region (K4) of 1.3 shall be considered for tower design. c) The number of consecutive spans between the section points/ angle point shall not exceed 10 spans or 3 km instead of conventional practice of 15 spans or 5 km, in order to reduce the failure of such towers in coastal areas due to cascading effect. The section shall be terminated with tension tower/ angle tower and angle of deviation should be based on the site requirement. A.18.0 Wherever, transmission lines are passing through cyclone prone areas (i.e. areas up to 60 km from coast)/ creek regions/ aggressive soil areas following shall also be applicable: a) The fabricated tower parts and stubs shall have a minimum overall zinc coating of 900 g/m2 of surface area except for plates and sections below 5 mm which shall have a minimum overall zinc coating of 610 g/m2 of surface area. The average zinc coating for all sections and plates 5 mm and above shall be maintained as 127 microns and that for plates and sections below 5 mm shall be maintained as 87 microns. [Insert Name of the SPV] 91 ……2026Transmission Service Agreement b) Ready mix concrete of M30 Grade shall be used to avoid use of locally available saline water. However, design mix concrete of M30 Grade conforming to IS 456 with potable water can be used at locations where transportation of ready-mix concrete is not feasible. Minimum cement content in any case shall not be less than 330 kg/m3. c) The surface of the reinforced steel shall be treated with epoxy-based coating to enhance corrosion performance of foundation. Use of epoxy coated reinforcement in foundation shall be as per IS 13620. In addition, two (2) coats of bituminous painting of minimum 1.6 kg/m2 per coat shall be applied on all exposed faces of foundation (i.e. pedestal and base slab). d) Double coat 20 mm thick cement plaster shall be provided on all exposed concrete surface as well as up to 300 mm below the ground level to provide protection to concrete surface from environmental and saline effect. e) Before coping of chimney top portion, three coats of anti-corrosive paint of minimum 30-35 microns dry film thickness each shall be applied on the stub in the 50 mm coping portion as well as up to 350 mm above CL portion. A.19.0 The raised chimney foundation is to be provided in areas prone to flooding/water stagnation like paddy field /agricultural field and undulated areas to avoid direct contact of water with steel part of tower. The top of the chimney of foundation should be at least above High Flood Level (HFL) or the historical water stagnation/ logging level (based on locally available data) or above High Tide Level or 500 mm above Natural Ground level (whichever is higher). A.20.0 Routing of transmission line through protected areas shall be avoided to the extent possible. In case, it is not possible to avoid protected areas, the towers of the transmission line up to 400 kV level, which are installed in protected areas shall be designed for Multicircuit (4 circuits) configuration of same voltage level considering reliability level of at least two (2). The top two circuits of these multi- circuit towers shall be used for stringing of the transmission line under present scope and the bottom two circuits shall be made available for stringing of any future transmission line of any transmission service providers/ State transmission utilities/Central transmission utilities passing through the same protected area. Further, the configuration and coordinates of such transmission towers shall be submitted to CEA, CTU and BPC by the TSP. A.21.0 The TSP shall abide by the Guidelines of CEA w.r.t. shifting of transmission lines for NHAI projects and other projects. A.22.0 Safety precautions in regards to gas/oil pipelines in vicinity of Transmission lines shall be taken in coordination with gas/ petroleum authorities. [Insert Name of the SPV] 92 ……2026Transmission Service Agreement A.23.0 The stringing of the transmission line in the forest area shall be carried out through drones. A.24.0 The tower shall be designed considering the porcelain Insulators with creepage factor of 31 mm/ kV irrespective of type of insulator used. A.25.0 RoW width and Span in different terrain shall be as per Schedule VII of CEA (Technical Standards for Construction of Electrical plants and Electric Lines) Regulations 2022 as amended from time to time. [Insert Name of the SPV] 93 ……2026Transmission Service Agreement SPECIFIC TECHNICAL REQUIREMENTS FOR SUBSTATION The proposed Pendurthi (Vizag) S/s shall be conventional Gas Insulated Switchgear (GIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations, 2022, as amended from time to time. The proposed Khammam-II S/s shall be conventional Air Insulated Switchgear (AIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Extension of proposed Srikakulam S/s shall be conventional Gas Insulated Switchgear (GIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Extension of proposed Khammam S/s and Warangal New S/s shall be conventional Air Insulated Switchgear (AIS) type conforming to the requirements of CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Other CEA Regulations/guidelines as amended up to date and MoP guidelines, as applicable, shall also be followed. B.1.0 Salient features of Substation Equipment and Facilities The design and specification of substation equipment are to be governed by the following factors: B.1.1 Insulation Coordination The system design parameters for substations/switchyards shall be as given below: [Insert Name of the SPV] 94 ……2026Transmission Service Agreement Sl. Description of 765/400kV 765/400 kV parameters No. Khammam-II S/s (AIS) Pendurthi (Vizag) S/s (GIS) 765 kV 400 kV 765 kV 400 kV System System System System 1. System 765 kV 400 kV 765 kV 400 kV Operating Voltage 2. Maximum voltage 800 kV 420 kV 800 kV 420 kV of the system (rms) 3. Rated Frequency 50 Hz 50 Hz 50 Hz 50 Hz 4. No. of Phases 3 3 3 3 5. Rated Insulation Levels i) Lightning Impulse Withstand Voltage for (1.2/50 micro 2100 kVp 1425 kVp 2100 1425 sec.) kVp kVp for Equipment 2100 kVp 1550 kVp other than 2100 Transformer and kVp 1550 Reactor kVp for Insulator String ii) Switching 1550 kVp 1050 kVp 1425 kVp 1050 Impulse kVp (for GIS) withstand voltage (250/2500 micro 1550 kVp sec.) dry and wet (for AIS) [Insert Name of the SPV] 95 ……2026Transmission Service Agreement Sl. Description of 765/400kV 765/400 kV parameters No. Khammam-II S/s (AIS) Pendurthi (Vizag) S/s (GIS) 765 kV 400 kV 765 kV 400 kV System System System System iii) One minute 830 kV 630 kV 960 kV 650 kV power frequency (for GIS) (for GIS) dry withstand voltage (rms) 830 kV 630 kV (for AIS) (for AIS) 6. Corona Extinction 508 kV 320 kV 508 kV 320 kV Voltage 7. Max. radio 2500 1000 2500 1000 interference micro-volts micro- micro-volt micro- voltage for volts at 508 volt at frequency at 508 kV kV rms 266 kV between 0.5 MHz rms at 266 kV rms and 2 MHz rms 8. Minimum 24800 mm 13020 24800 13020 creepage mm mm mm distance for (31mm/kV) (31 (31 (31 insulator string/ mm/kV) mm/kV) mm/kV) longrod insulators/ outdoor bushings 9. Minimum 20000 mm 10500 24800 13020 creepage mm mm mm (25 distance for mm/kV) (25 (31 (31 switchyard mm/kV) mm/kV) mm/kV) equipment 10. Max. Fault 50 kA 63 kA 50 kA 63 kA Current [Insert Name of the SPV] 96 ……2026Transmission Service Agreement Sl. Description of 765/400kV 765/400 kV parameters No. Khammam-II S/s (AIS) Pendurthi (Vizag) S/s (GIS) 765 kV 400 kV 765 kV 400 kV System System System System 11. Duration of Fault 1 sec 1 sec 1 sec 1 sec Sl. Description of 765 kV 765 kV 400 kV parameters No. Srikakulam Warangal Khammam S/s (GIS) New S/s S/s (AIS) (AIS) 765 kV 765 kV 400 kV System System System 1. System Operating 765 kV 765 kV 400 kV Voltage 2. Maximum voltage of 800 kV 800 kV 420 kV the system (rms) 3. Rated Frequency 50 Hz 50 Hz 50 Hz 4. No. of Phases 3 3 3 5. Rated Insulation Levels i) Lightning Impulse withstand voltage for (1.2/50 micro sec.) 2100 kVp 2100 kVp 1425 kVp for Equipment other than Transformer and Reactor 2100 kVp 1550 kVp for Insulator String [Insert Name of the SPV] 97 ……2026Transmission Service Agreement Sl. Description of 765 kV 765 kV 400 kV parameters No. Srikakulam Warangal Khammam S/s (GIS) New S/s S/s (AIS) (AIS) 765 kV 765 kV 400 kV System System System 2100 kVp ii) Switching Impulse 1425 kVp 1550 kVp 1050 kVp withstand voltage (for GIS) (250/2500 micro sec.) dry and wet 1550 kVp (for AIS) iii) One minute power 960 kV 830 kV 630 kV frequency dry (for GIS) withstand voltage (rms) 830 kV (for AIS) 6. Corona Extinction 508 kV 508 kV 320 kV Voltage 7. Max. radio 2500 2500 1000 interference voltage micro-volt at micro-volts micro-volts for frequency between 508 kV rms 0.5 MHz and 2 MHz at 508 kV at 266 kV rms rms 8. Minimum creepage 24800 mm 24800 mm 13020 mm distance for insulator (31 mm/kV) (31 mm/kV) (31 mm/kV) string/ longrod insulators/ outdoor bushings [Insert Name of the SPV] 98 ……2026Transmission Service Agreement Sl. Description of 765 kV 765 kV 400 kV parameters No. Srikakulam Warangal Khammam S/s (GIS) New S/s S/s (AIS) (AIS) 765 kV 765 kV 400 kV System System System 9. Minimum creepage 24800 mm 20000 mm 10500 mm distance for (31 mm/kV) (25 mm/kV) (25 mm/kV) switchyard equipment 10. Max. Fault Current 50 kA 50 kA 63 kA 11. Duration of Fault 1 sec 1 sec 1 sec B.1.2 Switching Scheme The switching schemes, as mentioned below, shall be adopted at various voltage levels of substation/switchyard: Substation 765 kV side 400 kV side 765/400 kV Pendurthi (Vizag) S/s One and Half One and Half (GIS) breaker breaker 765/400 kV Khammam-II S/s (AIS) One and Half One and Half breaker breaker 765 kV Srikakulam S/s (GIS) One and Half ------ breaker 765 kV Warangal New S/s (AIS) One and Half ------ breaker 400 kV Khammam S/s (AIS) ------ One and Half breaker Notes: - i) For one and half breaker switching scheme, any double circuit line consisting of two numbers of feeders and originating from the same transmission or generating switchyard shall not be terminated in one diameter. ii) Two transformers of same HV rating shall not be connected in the same [Insert Name of the SPV] 99 ……2026Transmission Service Agreement diameter and similarly two bus reactors of same HV rating shall also not be connected in the same diameter. iii) A diameter in one and half breaker scheme is a set of 3 circuit breakers with associated isolators, earth switches, current transformers etc. for controlling 2 (two) numbers of feeders. iv) In case of GIS substation where the bus scheme is One and Half breaker scheme, the diameters shall be complete with feeder/line side isolator and GIS duct of the future bay shall be brought outside the GIS hall/building with extension/interface module suitably. v) Connection arrangement of Switchable Line reactors shall be such that it can be used as Line reactor as well as Bus reactor with suitable NGR bypass arrangement. vi) Space for 765 kV and 400 kV future line bays shall be kept considering provision of switchable line reactors. vii) Provision for Bus sectionalizer: Space for One (1) set of bus sectionalizer for 400 kV shall comprise Two (2) Nos. of bus sectionalizer bays with associated Circuit Breakers, Isolators and Current Transformers for both buses. Space for One (1) set of bus sectionalizer for 220 kV shall comprise Two (2) Nos. of bus sectionalizer bays with associated Circuit Breakers, Isolators and Current Transformers for both buses. viii) TSP shall plan connectivity of line and transformer feeders to bus bar in such a way that all power can be evacuated successfully without crossing the thermal limit at any point of bus-bar. ix) For AIS type substation, TSP shall keep space provisions for future elements such that interconnection arrangement to the corresponding future bays can be done with overhead AIS type connection without any cable/ GIS duct. x) 765/400 kV Pendurthi (Vizag) S/s: 765 kV bay configurations (one and half breaker scheme) shall be as follows: Configuration Numbers ICT- Tie- Line 4 (four) Bus Reactor-Tie-Future Line with Switchable Line 1 (one) Reactor* 400 kV bay configurations (one and half breaker scheme) shall be as follows: [Insert Name of the SPV] 100 ……2026Transmission Service Agreement Configuration Numbers ICT (400 kV side of 765/400 kV ICT)- Tie- Line 4 (four) STATCOM-Tie-Future Line with Switchable Line 1 (one) Reactor* Note (*): GIS modules for Line Bay and Switchable Line Reactor shall be provided by TSP under present scope. xi) 765/400 kV Khammam-II S/s: 400 kV Bus Sectionalization shall be with the following feeder distribution. 400 kV Bus Section-1 400 kV Bus Section-2 (future) a) 3 Nos. of Present 765/400 kV a) 3 Nos. of future765/400 kV ICT ICT b) 2 Nos. of Present 400 kV Lines b) 5 Nos. of future 400/220 c) 5 Nos. of future 400/220 kV ICT kV ICT d) 4 Nos. of Future 400 kV Lines c) 6 Nos. of Future 400 kV (with provision for Switchable line Lines (with provision for reactor) Switchable line reactor) TSP shall implement 400 kV bays keeping the space provision for providing 400 kV Bus Sectionalizer in future meeting the requirements of feeder distribution as mentioned above. xii) 765 kV Srikakulam S/s: Pendurthi (Vizag) - Srikakulam 765 kV D/c line shall be terminated in 2 nos. of existing diameters. GIS modules for these Line Bays and Switchable Line Reactor at Srikakulam is being implemented under the scheme “Inter-Regional Strengthening between SR Grid and ER Grid”. Switchable Line Reactor, Line termination equipment (such as SF6 to Air Bushings with associated GIS duct, LA, CVT and Wave trap), Protection panels, PLCC etc. as required shall be provided under present scope. xiii) 765 kV Warangal New S/s: - Khammam-II – Warangal New 765 kV D/c line shall be terminated in 2 nos. of new diameters (Line bays 704 and 707) for which Main and Tie bays shall be constructed under present scope. Refer attached SLD-5427PS102-WGL-E-SYD-SYS-0001-SL, Rev 3 at B.5. xiv) 400 kV Khammam S/s: One circuit of Khammam-II - Khammam 400 kV D/c line shall be terminated in existing diameter for which Main Bay shall be provided under present scope. Other circuit shall be terminated in new diameter for which Main bay and Tie bay shall be provided under present [Insert Name of the SPV] 101 ……2026Transmission Service Agreement scope. xv) In one and half breaker scheme, both main bay and tie bay shall be completed for controlling a feeder. Further, all associated interconnection work shall also be in the present scope of TSP. B.2.0 Substation Equipment and Facilities (Voltage level as applicable): The switchgear shall be designed and specified to withstand operating conditions and duty requirements. All equipment shall be designed considering the following capacity. 765/400 kV Pendurthi 765/400 kV Khammam-II Sl. Description of (Vizag) S/s (GIS) S/s (AIS) No Bay 765 kV 400 kV 765 kV 400 kV 1. Bus Bar 5000 A 5000 A 4000 A 4000 A 2. Line bay 3150 A 3150 A 3150 A 3150 A 3. ICT bay 3150 A 3150 A 3150 A 3150 A 4. Reactor bay 3150 A N/A 3150 A N/A 5. STATCOM Bay N/A 3150 A N/A N/A 765 kV Srikakulam 765 kV 400 kV Sl. Description of S/s Warangal New Khammam S/s No Bay (GIS) S/s (AIS) (AIS) 765 kV 765 kV 400 kV 1. Bus Bar As per existing As per existing As per existing 2. Line bay 3150 A 3150 A 3150 A 3. Reactor bay 3150 A N/A N/A B.2.1 (765/3)/(400/3)/33 kV, Single Phase Autotransformer 500 MVA, (765/3)/ (400/3)/ 33 kV, 1-phase autotransformer (including arrangement for 3-phase bank formation of 1500 MVA) shall conform to CEA’s “Standard Specifications and Technical Parameters for Transformers and Reactors (66 kV and above Voltage Class)” as amended up to date available on CEA’s website. Spare 1-phase Transformer unit shall be placed and connected in such a way that the spare unit can be utilized to replace any unit of any of the transformer banks (including for future transformer banks) without physically moving it. B.2.2 (765/3) kV, Single Phase Shunt Reactor 110 MVAr, 765/3 kV, 1-Phase Reactor (including arrangement for 3-phase bank formation of 330 MVAr) shall conform to CEA’s “Standard Specifications [Insert Name of the SPV] 102 ……2026Transmission Service Agreement and Technical Parameters for Transformers and Reactors (66 kV and above voltage class)” as amended up to date available on CEA website. Spare 1-phase Shunt Reactor unit shall be placed and connected in such a way that the spare unit can be utilized for all the bus and switchable line reactor banks (including for future reactor banks) without its physical movement. Neutral Grounding Reactor and Surge Arrester for 765 kV Switchable Line Reactors (as applicable): The neutral of the switchable line reactors (wherever provided) shall be grounded through adequately rated Neutral Grounding Reactors (NGR) to facilitate single phase auto-reclosure, provided that the NGR shall be provided with suitable bypass arrangement so that the switchable line reactor can be used as bus reactor as and when required. The neutral of bus reactor shall be solidly grounded. NGR shall be oil filled or dry type air core for outdoor application. NGR shall conform to CEA’s “Standard specifications and technical parameters of transformers and reactors (66 kV and above Voltage Class)”, as amended up to date. Technical parameters of NGR shall be as specified in Annexure-A of above-mentioned document. The surge arresters (rated voltage of arrester in co-ordination with ohmic value of NGR shall be decided by the TSP) shall be provided and physically located between the neutral of shunt reactor (brought out at 145 kV class bushing) and neutral grounding reactor. The surge arresters shall be of Station Medium (SM) class duty gapless Metal Oxide (ZnO) type conforming in general to IEC-60099- 4. Arresters shall be hermetically sealed units, of self-supporting construction, suitable for mounting on structures. The Ohmic value of NGR for Line Reactors shall be as follows: Sl. No. Line Name Substation Name NGR value (Ohm) 1. Pendurthi (Vizag) – Srikakulam Srikakulam S/s 500 765 kV D/c line (about 200 km) with 330 MVAr SLR (convertible) at Srikakulam end on both circuits 2. Khammam-II – Pendurthi Pendurthi (Vizag) 400 (Vizag) 765 kV D/c line (about S/s 350 km) with 330 MVAr SLR Khammam-II S/s 400 (convertible) at both ends on both circuit [Insert Name of the SPV] 103 ……2026Transmission Service Agreement B.2.3 765 kV and 400 kV GIS Substation equipment GIS (Gas Insulated Switchgear) shall be Indoor type in accordance to IEC: 62271-203. The switchgear shall be designed and specified to withstand operating conditions and duty requirements. All the switchgear such as Circuit Breaker, isolator, earth switch including CT, PT etc. shall be GIS type. The Surge Arrestor and Voltage Transformer shall be either GIS or outdoor AIS type. The GIS assembly shall consist of separate modular compartments e.g. Circuit Breaker compartment, Bus bar compartment filled with SF Gas and separated 6 by gas tight partitions so as to minimize risk to human life, allow ease of maintenance and limit the effects of gas leaks failures and internal arcs etc. These compartments shall be designed to minimize the risk of damage to adjacent sections and protection of personnel in the event of a failure occurring within the compartments. Rupture diaphragms with suitable deflectors shall be provided to prevent uncontrolled bursting pressures developing within the enclosures under worst operating conditions, thus providing controlled pressure relief in the affected compartment. The arrangement of gas sections or compartments shall be such as to facilitate future extension of any make without any drilling, cutting or welding on the existing equipment. To add equipment, it shall not be necessary to move or dislocate the existing switchgear bays. The layout of Gas Insulated Bus Ducts shall be properly planned to optimize the length of bus ducts and for easy accessibility for maintenance. The length of busbars, bus ducts, isolator sections shall be optimized considering effects of fast transient voltage due to isolator operations. The bus bar modules including auxiliary bus modules (wherever applicable) shall be provided with suitable End Piece (Interface) module on both sides with the test link facility for future extension as per provisions of future requirements. The end piece module shall be designed in such a way so that future GIS modules may be tested without extending test voltage to existing bus and vice- versa by removing the test link. TSP shall make available the complete details for the design of interface module such as cross section, enclosure material, enclosure dimensions (inner and outer), Flange diameter (inner and outer), conductor cross-section and connection arrangement, bolt spacing and dimension, rated gas pressure, Gasket detail etc. Further, adequate space for GIS busbar interface module shall be taken into account for future scope. Each section shall have plug-in or easily removable connection pieces to allow for easy replacement of any component with the minimum disturbance to the remainder of the equipment. Inspection windows (View Ports) shall be provided for Disconnector Switches and both type of earth switches i.e. Maintenance and fast operating. [Insert Name of the SPV] 104 ……2026Transmission Service Agreement Local Control Cabinets (LCC) shall be provided as per requirement. The alarm and annunciation of GIS equipment shall be wired to the SCADA System. The material and thickness of the enclosures shall be such as to withstand an internal flashover without burns through for a period of 300 ms at rated short time withstand current. The material shall be such that it has no effect of environment as well as from the by-products of SF breakdown under arcing 6 conditions. This shall be validated with Type Test. Service continuity requirement for GIS: The GIS equipment with the given bus switching arrangement shall be divided into different gas compartments. During the work such as a fault repair or major maintenance, requiring the dismantling of a gas compartment for which more than one compartments may need to be de-gassed. TSP shall meet following Service continuity conditions (to the extent possible) with ensuring equipment and operating personnel’s safety:  For One and half breaker bus switching scheme, during a fault in Circuit Breaker compartment, no bus bar and feeder is permitted out of service during maintenance and repair/replacement.  During a fault in a GIS compartment other than the Circuit Breaker compartment, maximum of one bus bar and/or one feeder is permitted out of service during maintenance and repair/replacement. UHF sensors in GIS for PD (Partial Discharge) detection: The adequate number of Ultra High Frequency (UHF) sensors shall be provided in the offered GIS along with suitable portable type Partial Discharge (PD) measuring instrument for detection of Partial discharge (of 5 pC and above as per IEC 60270). The number and location of these sensors shall be based on laboratory tests on the typical design of GIS as per recommendations of CIGRE Document No. 654 (Application Guide for sensitivity verification for UHF Partial discharge detection system for GIS). B.2.3.1 Circuit Breakers (GIS) GIS Circuit breakers shall in general be of C2-M2 class and comply to IEC- 62271-100. The rated break time shall not exceed 40 ms (milli second) for 765 kV and 400 kV. Circuit breakers shall be suitable for single phase and three phase auto reclosing. Each breaker would have two sets of trip circuits which would be connected to separate DC supplies for greater reliability. The Circuit breakers controlling 765 kV lines shall be provided either with pre-insertion closing resistor of about 450 ohms with 9 ms insertion time or with Controlled Switching Device (CSD). The Circuit breakers controlling 400 kV lines wherever required shall be provided with pre-insertion closing resistor of about 400 ohms with 8 ms insertion time or Controlled Switching Device (CSD) for lines longer [Insert Name of the SPV] 105 ……2026Transmission Service Agreement than 200 km. The short line fault capacity shall be the same as the rated capacity and this is proposed to be achieved without use of opening resistors. Controlled switching device shall be provided in the Circuit Breaker of the switchable line reactor bay and in Main and Tie bay circuit breakers of line with non-switchable line reactors, Bus reactors and Transformers for 400 kV and above voltage class. B.2.3.2 Isolators (GIS) The isolators shall comply to IEC 62271-102 in general. Earth switches shall be provided at various locations to facilitate maintenance. Main blades and earth blades shall be interlocked and interlock shall be fail safe type. All isolators and earth switches shall be motor operated type. The isolator shall be of extended mechanical endurance class-M2 and suitable for Bus Transfer Current Switching duty as per IEC standards. High speed earthing switches shall be provided for grounding purposes at overhead line terminations and cable terminations and shall have fault making capability as specified. Earth switch for line isolator shall be of earthing switch class E1 and shall be suitable for induced current switching duty as defined for Class-B as per relevant standard. B.2.3.3 Current Transformers (GIS) Current Transformers shall comply with IEC 61869 in general. All ratios shall be obtained by secondary taps only. Generally, Current Transformers (CT) shall have five cores (four for protection and one for metering) whereas; CT in Tie bays shall have six cores (four for protections and two for metering) suitably distributed on both sides of CB (for 400 kV and above voltage class).The burden and knee point voltage shall be in accordance with the requirements of the system including possible feeds for telemetry. The accuracy class for protection core shall be PX and for the metering core it shall be 0.2S. The rated burden of cores shall be closer to the maximum burden requirement of metering and protection system (not more than 20 VA for metering core) for better sensitivity and accuracy. The instrument security factor shall be less than 5 for CTs up to 400 kV voltage class and less than 10 for CTs of 765 kV voltage class. B.2.3.4 Voltage Transformer (GIS) The voltage transformers shall conform to IEC-61869. Voltage transformers shall be of electromagnetic type with SF gas insulation. The earth end of the 6 high voltage winding and the ends of the secondary winding shall be brought out in the terminal box. The voltage transformers shall be located as a separate bay module and will be connected phase to ground and shall be used for protection, metering and synchronization. The voltage transformers shall be of [Insert Name of the SPV] 106 ……2026Transmission Service Agreement inductive type, nonresistant and shall be contained in their own-SF 6 compartment, separated from other parts of installation. The voltage transformer shall be effectively shielded against high frequency electromagnetic transients. The voltage transformer shall have three secondary windings out of which two shall be used for protection and one for metering. The voltage transformer should be thermally and dielectrically safe when the secondary terminals are loaded with the guaranteed thermal burdens. The accuracy class for protection cores shall be 3P. The accuracy of 0.2 on metering core should be maintained throughout the entire burden range on all the three windings without any adjustments during operation. The rated burden of cores shall be closer to the maximum burden requirement of metering and protection system (not more than 50 VA for metering core) for better sensitivity and accuracy. B.2.3.5 Surge Arresters (GIS) (if applicable) 624 kV Station High (SH) duty and 336 kV Station High (SH) duty gapless type Surge arresters with thermal energy (Wth) of minimum 13 kJ/ kV and 12 kJ/ kV respectively shall be provided for 800 kV and 420 kV system respectively conforming to IEC 60099-4 in general. Other characteristics of Surge arrester shall be chosen in accordance with system requirements. Surge arresters shall be provided at line entrances, near transformers and reactors so as to achieve proper insulation coordination. A leakage current monitor with surge counter shall be provided with each surge arrester. B.2.3.6 SF to Air Bushing 6 Outdoor bushings, for the connection of conventional external conductors to the SF metal enclosed switchgear, shall be provided. Bushings shall generally be 6 in accordance with the requirements of IEC-60137. The creepage distance over the external surface of outdoor bushings shall not be less than 31 mm/ kV. SF 6 to air Bushing shall be of Polymer/ composite type and shall be robust and designed for adequate cantilever strength to meet the requirement of seismic conditions. The electrical and mechanical characteristics of bushings shall be in accordance with IEC-60137. Polymer/composite insulator shall be seamless sheath of silicon rubber compound. The housing and weather sheds should have silicon content of minimum 30% by weight. It should protect the bushing against environmental influences, external pollution and humidity. The hollow silicon composite insulators shall comply with the requirements of IEC 61462 and the relevant parts of IEC-62217. B.2.4 765 kV and 400 kV AIS Substation equipment (as applicable) B.2.4.1 Circuit Breakers (AIS) The circuit breakers and accessories shall conform to IEC: 62271-100, IEC: 62271-1 and shall be of SF Type. The circuit breakers shall be of class C2-M2 6 [Insert Name of the SPV] 107 ……2026Transmission Service Agreement (as per IEC) with regard to restrike probability during capacitive current breaking and mechanical endurance. The rated break time shall not exceed 40 ms for 765 kV and 400 kV circuit breakers. The 765 kV and 400 kV circuit breakers shall be provided with single phase and three phase auto reclosing. Each breaker would have two sets of trip circuits, which would be connected to separate DC supplies for greater reliability. The circuit breakers controlling 765 kV lines shall be provided either with pre-insertion closing resistor of about 450 ohm maximum with 9 ms insertion time or with Controlled Switching Device. The Circuit breakers controlling 400 kV lines shall be provided with pre insertion closing resistor of about 400 ohm with 8 ms insertion time or Controlled Switching Device (CSD) for lines longer than 200 km length. The short line fault capacity shall be same as the rated capacity and this is proposed to be achieve without use of opening resistors. The controlled switching device shall be provided in circuit breakers of switchable line reactor bay and in Main and Tie bay circuit breakers of line with non-switchable line reactors, Bus Reactors and Transformers of voltage class 400 kV and above. B.2.4.2 Isolators (AIS) The Isolators shall comply with IEC 62271-102 in general. 765 kV Isolator design shall be double break or vertical break or knee-type. 400 kV Isolators shall be double break type. All Isolators and earth switches shall be motor operated. Earth switches shall be provided at various locations to facilitate maintenance. Isolator rated for 400 kV shall be of extended mechanical endurance class – M2 as per IEC-62271-102. Main blades and earth blades shall be interlocked and interlock shall be fail safe type. The 765 kV and 400 kV earth switches for line isolator shall be suitable for induced current switching duty as defined for Class-B. B.2.4.3 Current Transformers (AIS) Current Transformers shall comply with IEC 61869 in general. All ratios shall be obtained by secondary taps only. Generally, Current Transformers (CT) for 765 kV and 400 kV shall have six cores (four for protection and two for metering). The burden and knee point voltage shall be in accordance with the requirements of the system including possible feeds for telemetry. The accuracy class for the protection core shall be PX and for the metering core it shall be 0.2S. The rated burden of cores shall be closer to the maximum burden requirement of the metering and protection system (not more than 20 VA for metering core) for better sensitivity and accuracy. The instrument security factor shall be less than five (5) for CTs up to 400 kV and less than ten (10) for CTs of 765 kV voltage class. B.2.4.4 Capacitive Voltage Transformers (AIS) [Insert Name of the SPV] 108 ……2026Transmission Service Agreement Capacitive Voltage Transformers shall comply with IEC 61869 in general. These shall have three secondaries out of which two shall be used for protection and one for metering. The Accuracy class for protection cores shall be 3P and for metering core shall be 0.2. The Capacitive Voltage Transformers on lines shall be suitable for Carrier Coupling. The Capacitance of CVT for 400 kV shall be of 4400/8800 pF depending on PLCC requirements whereas the Capacitance of CVT for 765 kV shall be 8800 pF. The rated burden of cores shall be closer to the maximum burden requirement of metering and protection system (not more than 50 VA for metering core) for better sensitivity and accuracy. B.2.4.5 Surge Arresters (AIS) 624 kV and 336 kV Station High (SH) duty gapless type Surge Arresters with thermal energy (W ) of minimum 13 kJ/kV and 12 kJ/kV conforming to IEC th 60099-4 in general shall be provided for 800 kV and 420 kV systems respectively. Other characteristics of Surge Arrester shall be chosen in accordance with system requirements. Surge Arresters shall be provided at line entrances, near transformers and reactors so as to achieve proper insulation coordination. Surge Arresters shall be provided with porcelain/ polymer housing fitted with pressure relief devices. A leakage current monitor with surge counter shall be provided with each surge arrester. B.2.5 Protection Relaying and Control System The protective relaying system proposed to be provided for transmission lines, auto-transformers, reactors and bus bars to minimize the damage to the equipment in the events of faults and abnormal conditions, is dealt in this section. All main protective relays shall be numerical type with IEC 61850 communication interface and should have interoperability during integration of numerical relays to communicate over IEC61850 protocol with RTU/SAS/IEDs of different OEMs. All numerical relays shall have built in disturbance recording feature. The protection circuits and relays of the transformer and reactor shall be electrically and physically segregated into two groups each being independent and capable of providing uninterrupted protection even in the event of one of the protection groups failing, to obtain redundancy, and to take protection systems out for maintenance while the equipment remains in service. a) Transmission Lines Protection 765 kV and 400 kV lines shall have Main-I numerical three zone distance protection scheme with carrier aided inter-tripping feature. 765 kV and 400 kV lines shall also have Main-II numerical distance protection scheme like Main-I but from different make that of Main-I. The Main-I and Main-II protection relays [Insert Name of the SPV] 109 ……2026Transmission Service Agreement of same make may be provided only if they are of different hardware and manufacturing platform or different principle of operation. However, Line Current Differential Relay (with back up distance protection feature) as Main–I and Main-II shall be considered at both ends for short lines (line length below 30 km) having Fiber Optic Communication Link. Differential relay at remote end shall be provided by the TSP. The associated power and control cabling and integration with SAS at remote end shall be provided by respective bay owners. In case of loop in loop out of transmission lines, the existing protection scheme shall be studied and suitable up-gradation (if required) shall be carried out. Further, all 765 kV and 400 kV lines shall be provided with single and three phase auto- reclosing facility to allow reclosing of circuit breakers in case of transient faults. These lines shall also be provided with distance to fault locators to identify the location of fault on transmission lines. All 765 kV and 400 kV lines shall also be provided with two stage over voltage protection. The over voltage protection and distance to fault locator may be provided as in-built feature of Main-I and Main-II protection relays. Auto reclose as built-in function of Bay Control Unit (BCU) is also acceptable. The Main-I and Main-II protection relays shall be fed from separate DC sources and shall be mounted in separate panels. For 765 kV and 400 kV transmission lines, directional Inverse Definite Minimum Time (IDMT) earth fault relay should be provided as standalone unit or in-built feature of Main-I and Main -II feature. b) Auto Transformer Protection These shall have the following protections: i) Numerical Differential Protection ii) Numerical Restricted Earth Fault Protection iii) Numerical Back-up Over-Current and Earth Fault Protection on High Voltage (HV) and Intermediate Voltage (IV) side iv) Numerical Over Fluxing Protection on HV and IV side v) Numerical Overload Alarm Further, Numerical Back-up Over-current and earth fault protection on HV and IV side of auto-transformer shall not be combined with other protective functions in the main relays and shall be independent relays. Besides these, power transformers shall also be provided with Buchholz relay, Magnetic Oil Gauge (MOG) with low oil level alarm, protection against high oil and winding temperature and pressure relief device etc. [Insert Name of the SPV] 110 ……2026Transmission Service Agreement Suitable monitoring, control (operation of associated circuit breaker and isolator) and protection for LT auxiliary transformer connected to tertiary winding of auto-transformer for the purpose of auxiliary supply shall be provided. The over current and other necessary protection shall be provided for the auxiliary transformer. These protection and control may be provided as built- in feature either in the bay controller to be provided for the auxiliary system or in the control and protection IEDs to be provided for autotransformer. c) 765 kV Reactor Protection Reactor shall be provided with the following protections: i) Numerical Differential Protection. ii) Numerical Restricted Earth Fault Protection iii) Numerical Back-up impedance protection Besides these, reactors shall also be provided with Buchholz relay, Magnetic Oil Gauge (MOG) with low oil level alarm, protection against oil and winding temperatures and pressure relief device, etc. d) Bus bar Protection The high-speed low impedance type bus bar differential protection, which is essential to minimize the damage and maintain system stability at the time of bus bar faults, shall be provided for 765 kV and 400 kV buses. Duplicated bus bar protection is envisaged for 765 kV and 400 kV bus-bar protection. Bus bar protection scheme shall be such that it operates selectively for each bus and incorporate necessary features required for ensuring security. Bus Bar protection system for new substation shall be de-centralized (distributed) type. The scheme shall have complete bus bar protection for present as well as envisaged future bays i.e. input/ output modules for future bays for the bus sections under present scope shall be provided. Peripheral Units (PUs) shall be provided by the respective bay owners. In case, the bus section is provided, then each side of bus section shall have separate set of bus bar protection schemes. For existing substations, the existing bus bar protection shall be augmented as per requirement. e) Local Breaker Back up Protection This shall be provided for each 765 kV and 400 kV circuit breakers and will be connected to de-energize the affected stuck breaker from both sides. Notes: [Insert Name of the SPV] 111 ……2026Transmission Service Agreement 1. LBB and REF relays shall be provided separately from transformer differential relay. 2. LBB relay may also be provided as built-in protection function of distributed bus bar protection scheme; however in such case separate LBB relay shall be provided for tie bays (in case of One and Half breaker scheme). 3. Over fluxing and overload protection can be provided as built-in feature of differential relay. 4. In 765 kV and 400 kV switchyard, if spare bay of half diameter is identified as future, Tie CB relay panel shall be with Auto-reclosure feature. B.2.6 Substation Automation System a) For all the new substations, state of art Substation Automation System (SAS) conforming to IEC-61850 shall be provided. The distributed architecture shall be used for Substation Automation System, where the controls shall be provided through Bay Control Units. The Bay Control Unit is to be provided bay wise for voltage level 220 kV and above. All Bay Control Units as well as protection units are normally connected through an Optical fibre high speed network. The control and monitoring of circuit breaker, dis-connector, re-setting of relays etc. can be done from Human Machine Interface (HMI) from the Control Room. The functions of control, annunciation, disturbance recording, event logging and measurement of electrical parameters shall be integrated in the Substation Automation System. At the new substations, the Substation Automation System (SAS) shall be suitable for the operation and monitoring of the complete substation including proposed future bays/elements. In the existing substations with Substation Automation System (SAS), augmentation of existing SAS shall be done for bays under the present scope. In the existing Substations where Substation automation is not provided, control functions shall be done through control panels. Necessary gateway and modems (as required) shall be provided to send data to RLDC/SLDC as per their requirement and shall be provisioned with 2+2 redundancy i.e. 2 channels for Main Control Centre and 2 channels for Backup Control Centre. In order to meet this requirement, suitable redundancy at port and card level need to be ensured by the TSP to avoid any single point of failure which may lead to interruption in real-time grid operation. Accordingly, all the hardware for communication services of station as stated above shall support dual redundancy for data transmission of station to respective main and backup RLDCs. Any augmentation work at RLDC/SLDC is excluded from TSP’s scope. [Insert Name of the SPV] 112 ……2026Transmission Service Agreement However, all the configuration work at substation end required to send data to RLDC/SLDC shall be in the scope of TSP. b) Time Synchronization Equipment Time Synchronization Equipment complete in all respect including antenna, cable, processing equipment required to receive time signal through GPS/NavIC or from National Physical Laboratory (NPL) through INSAT shall be provided at new substations. This equipment shall be used to synchronize SAS and IEDs etc. B.3.0 Substation Support Facilities Certain facilities required for the operation and maintenance of substations as described below shall be provided at the new substation. In existing substation, these facilities have already been provided and shall be extended/ augmented as per requirement. B.3.1 AC and DC power supplies For catering the requirements of three phase and single phase AC supply and DC supply for various substation equipment (for present and future scope), the following arrangement is envisaged: iv) For LT Supply at each new Substation, two (2) Nos. of LT Transformers (minimum 800 kVA for substations with highest voltage rating as 765 kV) shall be provided which shall be fed from two independent sources as per the CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007. Metering arrangement with Special Energy Meters (SEMs) shall be provided by TSP at 33 kV tertiary of Transformer for drawing auxiliary supply at new substation. Such SEMs shall be provided by CTU at the cost of the TSP. Accounting of such energy drawn by the TSP shall be done by RLDC/RPC as part of Regional Energy Accounting. Additionally, Active Energy Meters may be provided at the same point in the 33 kV tertiary of Transformer by local SEB/DISCOM for energy accounting. v) 2 sets of 220V battery banks for control and protection and 2 sets of 48 V battery banks for PLCC/ communication equipment shall be provided at each new Substation. Each battery bank shall have a float-cum-boost charger. At new substation, sizing of 220 V battery and battery charger shall be done based on the number of bays specified (including future bays) as per CEA Regulations and relevant IS. 2 sets of 48 V battery banks for PLCC and communication equipment for present and future scope shall be provided at each new Substation with at least 10-hour battery backup and extended backup, if required. 48 V DC can be achieved from 220 V DC battery bank using adapter, if so desired by TSP, without compromising backup time. vi) Suitable AC and DC distribution boards and associated LT Switchgear shall be [Insert Name of the SPV] 113 ……2026Transmission Service Agreement provided at new substation. For new substation, following switch boards shall be considered with duplicate supply with bus coupler/ sectionalizer and duplicate outgoing feeders except for Emergency lighting distribution board which shall have only one incoming feeder: (a) 415 V Main Switch board – 1 No. (b) AC distribution board – 1 No. (c) Main lighting distribution board – 1 No. (d) Emergency lighting distribution board – 1 No. (e) 220 Volt DC distribution board – 2 Nos. (f) 48 Volt DC distribution board – 2 Nos. Sizing of LT Switchgear shall be suitable to cater the requirement for all present and future bays. AC and DC distribution boards shall have equipped modules for all the feeders (including future as specified). vii) At new Substation, one No. of DG set (minimum 500 kVA for substations with highest voltage rating as 765 kV) shall be provided for emergency applications. viii) For substation extensions, existing facilities shall be augmented as required. B.3.2 Fire Fighting System Fire-fighting system for substation including Transformer and Reactor shall conform to CEA (Measures Relating to Safety and Electric Supply) Regulations, 2023 as amended from time to time. Further, adequate water hydrants and portable fire extinguishers shall be provided in the substations. The main header of the firefighting system shall be suitable for extension to bays covered under the future scope; necessary piping interface in this regard shall be provided. Optical Beam type heat detection for GIS hall fire protection system shall be provided for all the GIS halls. At existing substations, the fire-fighting systems as available shall be extended to meet the additional requirements. B.3.3 Oil Evacuating, Filtering, Testing and Filling apparatus To monitor the quality of oil for satisfactory performance of transformers, shunt reactors and for periodical maintenance necessary oil evacuating, filtering, testing and filling apparatus would be provided at new substations. Oil storage tanks of adequate capacities for storage of transformer oil would be provided. Online Transformer Oil Drying Out System (TODOS) shall be provided in line with the provisions of Standard Specification and Technical Parameters for [Insert Name of the SPV] 114 ……2026Transmission Service Agreement Transformers and Reactors (66 kV and above Voltage Class) as amended up to date available on CEA website. B.3.4 Illumination Normal and emergency AC and DC illumination shall be provided adequately in the control room and other buildings of the substation. The switchyard shall also be provided with adequate illumination. The lighting of the entire control room building, fire-fighting pump house, other building (if any) and switchyard shall be done by LED based low power consumption luminaries. B.3.5 Control Room For the new substation, substation control room shall be provided to house substation work stations for station level control (SAS) along with its peripheral and recording equipment, AC and DC distribution boards, DC batteries and associated battery chargers, Fire Protection panels, Telecommunication panels and other panels as per requirements. Air conditioning shall be provided in the building as functional requirements. Main cable trenches from the control room shall have adequate space provision for laying of cables from the control room for all the future bays. At existing substations, the adequacy of size of control room shall be ascertained and the same shall be augmented as per requirement. B.3.6 GIS hall The Gas Insulated Switchgear (GIS) of each voltage level along with other associated equipment shall be housed inside separate GIS building. The panels i.e. Bay level units, bay mimic, relay and protection panels, RTCC panels, PLCC panels, panels for tele-communication system etc. are to be placed in a separate room in the GIS building. The size of the room shall be such that all the panels for the bays under present scope shall be accommodated. The panel room shall be air-conditioned. Further, the temperature of the room shall be monitored through substation automation system by providing necessary temperature transducers. Ventilation system of suitable capacity shall be provided for each GIS hall. GIS hall shall be constructed in such a way that its extension does not cause any hindrance to accommodate the bays of future expansion of substation. One EOT Crane of suitable capacity for erection and maintenance of largest GIS component/assembly and all plant installed in the GIS switchgear room shall be provided in each GIS hall. The crane shall be capable of fulfilling all special requirements for erection and maintenance of GIS equipment. The [Insert Name of the SPV] 115 ……2026Transmission Service Agreement capacity of the crane shall be sized to lift the heaviest GIS switchgear component. For extension of existing GIS, existing facilities shall be suitably augmented/ extended for GIS equipment under present scope. B.3.7 Control Concept All the EHV circuit breakers in substation/switching stations shall be controlled and synchronized from the switchyard control room/remote control center. All the isolators shall have control from remote/local whereas the earth switches shall have local control only. B.3.8 Visual Monitoring System (VMS) for watch and ward of substation premises: Visual Monitoring System for effective watch and ward of substation premises shall cover all the transformers and reactors, all other major AIS Equipment (such as CB, isolators, CT, CVT, SA etc. as applicable) , GIS bays, panel room, all the gates of switchyard and all entry and exit points of control room building and accordingly the location of cameras shall be decided. In addition to the gates of the switchyard, the cameras shall also be located around the boundaries at suitable locations. The camera shall be high-definition color CCD camera with night vision feature. The VMS data partly/completely shall be recorded (minimum for 15 days) at least @25fps (or better) and stored on network video recorder. The system shall use video signals from various cameras installed at different locations, process them for viewing on workstations/monitors in the control room and simultaneously record all the cameras. The VMS data should go only to the intended personnel/facility and not to the remote server of the Camera (VMS supplier). Mouse/keyboard controllers shall be used for pan, tilt, zoom and other functions of the desired camera. The Visual Monitoring System shall have provision of WAN connectivity for remote monitoring. All camera recordings shall have Camera ID and location/area of recording as well as date/time stamp. The equipment should generally conform to Electromagnetic compatibility requirement for outdoor equipment in EHV substation. Advisory on deployment of CCTV issued by Ministry of Electronics and Information Technology (MEITY) shall be followed. At existing substations, the Visual Monitoring System if available shall be augmented as per existing or better specification as required. [Insert Name of the SPV] 116 ……2026Transmission Service Agreement B.4 General Facilities a) Line Gantry/Towers are envisaged for bays under the present scope only. However, for adjacent future line bay, gantry/tower shall be designed for extension (considering Hexa conductors for 765 kV, Quad conductors for 400 kV and Twin conductor for 220 kV future lines) wherever applicable. b) Bay extension works at existing substation shall be executed by TSP in accordance with the requirements/provisions mentioned above. However, interface points shall be considered keeping in view the existing design/arrangement at the substation. c) TSP has to arrange for construction power and water on its own. d) All outdoor steel structures including anchor/foundation bolts shall be fully galvanized. The weight of the zinc coating shall be at least 610 g/m2, however, for coastal/creek regions it shall be at least 900 g/m2. (if applicable) e) In 765 kV and 400 kV switchyard, if spare bay of half diameter is identified as future, all the equipment for Tie and Future bay shall be designed considering the current rating of line bay i.e. 3150 A. f) Boundary wall shall be brick masonry wall with RCC frame or Stone masonry wall or Precast RCC wall under present scope along the property line of complete substation area including future switchyard area to prevent encroachment and unauthorized access. Minimum height of the boundary wall shall be of 1.8 m from Finished Ground Level (FGL). g) All electrical equipment shall be installed above the Highest Flood Level (HFL) and where such equipment is not possible to be installed above Highest Flood Level, it shall be ensured that there is no seepage or leakage or logging of water. h) As per CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022 /CEA Manual on Transmissions Planning criteria 2023, line approaching substation shall normally be perpendicular to the substation boundary for a stretch of 2-3 km. Accordingly, TSP shall ensure that line terminations at substations are arranged in a manner to avoid hindrance to future line terminations at the substations. [Insert Name of the SPV] 117 ……2026Transmission Service Agreement i) TSP shall finalize the substation site/layout such that the corridor for the termination of lines, including future lines at the substation, can be accommodated without any constraints. Accordingly, forests, large water bodies, or hills adjacent to the substation boundary should be avoided. B.5 EXTENSION OF EXISTING SUBSTATION The following drawings/details of existing substation are attached with the RfP documents for further engineering by the bidder. Sl. Drawing Title Drawing No./Details Rev. No. No. A. 765 kV Srikakulam S/s (GIS) 1.0 Single Line Diagram NHVS-EMC-SRKL-E-LAY- 3 DRG-001 ZF15-800 (50-9) 5KBJ.449.704 2.0 General Arrangement GA/Srikakulam 3.0 Earthmat Layout NHVS-EMC-645- SRKL-E-ERT-DRG- 0 002 4.0 Visual Monitoring System 5.0 Bus Bar Protection Schneider-Centralized bus bar scheme 6.0 Substation Automation Schneider Make (SCE System (SAS) Version: 4.85.06) B. 765 kV Warangal New S/s (AIS) 1.0 Single Line Diagram 5427PS102-WGL-E-SYD- R3 SYS-0001-SL 2.0 General Arrangement 5427PS102-WGL-E- R7 SYD-0001-GA [Insert Name of the SPV] 118 ……2026Transmission Service Agreement 3.0 Earthmat Layout 5427PS102-WGL-E- R0 SYD-SYS-0005-EW 4.0 Visual Monitoring System 5.0 Bus Bar Protection Make: GE Model: Micom 741 6.0 Substation Automation 5427PS102-WGL-U- System (SAS) A SYD-SAS-0013-AR C. 400 kV Khammam S/s (AIS) 1.0 Single Line Diagram C/Engg/Khammam_Extn/SLD 0 2.0 General Arrangement Attached - 3.0 Earthmat Layout - - 4.0 Visual Monitoring System 5.0 Bus Bar Protection 6.0 Substation Automation System (SAS) B.5.1 The existing drawings provided above and in subsequent amendments to the RfP are as received from the developer of existing substation and provided only for reference. Bidders shall follow the RfP for scope of work. Actual site conditions may be different due to other schemes being executed or subsequent revisions by the developer. Thus, Bidders are advised to visit the substation sites and acquaint themselves for details such as: i. Actual site conditions, Layout, Topography ii. Infrastructure such as roads, cable trench, drainage iii. Space availability in existing control room and LT panel room iv. Soil investigation v. Fire hydrant layout vi. SAS architecture and IO list vii. Boundary viii. Design philosophy etc. [Insert Name of the SPV] 119 ……2026Transmission Service Agreement SPECIFIC TECHNICAL REQUIREMENTS FOR STATCOM The proposed STATCOMs shall be conforming to the requirements of CEA (Technical Standards for Connectivity to Grid) Regulations, 2007 including amendments and CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations 2022, as amended from time to time. Other CEA Regulations and MoP guidelines, as applicable, shall also be followed and complied with. Note: These specifications are general in nature applicable to a STATCOM in combination of MSC and MSR. Since, +300 MVAr STATCOM along with 2x125 MVAr MSC has been specified under the present Scope of work at Pendurthi (Vizag) GIS, the specification may be read accordingly. C.1 Introduction: This technical specification for a STATCOM Station consists of STATCOM MSCs (Mechanically Switched Capacitors) and MSRs (Mechanically Switched Reactors) (to be installed at MV bus) including associated coupling Transformer (rated 400/xx kV) and other equipment connected to the 400 kV bus. MV voltage level (xx kV) of the coupling Transformer can be chosen by the TSP to optimize the offered solution which meets functional requirement of this Technical Specification. The STATCOM station shall operate asymmetrically in the leading and lagging MVAr regions as applicable to reach the dynamic range specified. The purpose of the STATCOM station is to regulate the voltage of 400 kV Bus Point of Common Coupling (PCC). The Configuration and the nominal rating of the STATCOM station is specified in this document. The main building block of the STATCOM should be single phase Voltage Source Converter (VSC) based convertor valve (multi-level) operating in a way to eliminate or minimize AC filter requirement to High pass filter only and connected to the xx kV bus through air core reactors. The ± 300 MVAr STATCOM with 2x125 MVAr Mechanically switched Capacitor (MSC) shall be with control switching arrangement for 330 MVAr, 765 kV. C.1.1 Definitions and Abbreviations For the purpose of this specification, the following definitions / abbreviations are used: [Insert Name of the SPV] 120 ……2026Transmission Service Agreement PCC: Point of Common Coupling (herein also called as Point of Interconnection (POI)) The connection point between the STATCOM and the ISTS at which performance requirements are defined. Reference Voltage (Vref): The Point on the voltage/current (V/I) characteristics where the static synchronous compensator (STATCOM) is at zero output (i.e. where no reactive power is absorbed from, or supplied to, the transmission system where the voltage is controlled) MV: Medium Voltage. STATCOM Unit: Static Synchronous Compensator based on Multi-Module technology and including air cored reactors as needed, Valve cooling, switchgear and its control and protection. STATCOM: Static Synchronous Compensator consisting of STATCOM Unit(s) connected to a common Coupling Transformer. A static synchronous generator operated as a shunt connected compensator, whose capacitive or inductive output current can be controlled independently of the AC system voltage. MSC: Mechanically Switched Capacitor (Including Switchgear). A shunt- connected circuit containing a mechanical power-switching device in series with a capacitor bank and a current limiting reactor. MSR: Mechanically Switched Reactor (Including Switchgear). A shunt- connected circuit containing a mechanical power-switching device in series with a reactor. Sub Module: Basic single power module of a Multi Module STATCOM unit Valve. It is a Part of a STATCOM unit valve comprising controllable switches and diodes connected in full bridge arrangement, together with their immediate auxiliaries, and storage capacitor, if any, where each controllable switch consists of one or more switched valve device(s) connected in series. Valve: Electrically and mechanically combined assembly comprising of forced commutated devices [for example insulated-gate bipolar transistor(IGBT)] assembled in levels, complete with all connections, auxiliary components, and mechanical structures, which can be connected in series with each phase of the reactor of a STATCOM unit. Valve Section: Electrical assembly defined for test purposes, comprising one of several sub-modules. Valve Structure: Physical structure holding valve(s), which is insulated to the full system voltage above earth potential. [Insert Name of the SPV] 121 ……2026Transmission Service Agreement STATCOM Station: STATCOM Station includes 400 kV Switchgear, Coupling Transformer, STATCOM, MSCs (as applicable), MSRs (as applicable) along with its switchgear and complete integrated control and protection whose outputs are coordinated. (Complete turnkey delivery at site). CT: Current Transformer. VT: Voltage Transformer. SAS: Substation Automation System. Response Time: the duration from a step change in control signal until the voltage changes by 90% of its final change, before any overshoot. Settling Time: The duration from a step change in control signal input until the STATCOM output settles to within +5% of the required control output. Slope: The ratio of the voltage change to the current change over a defined controlled range of the STATCOM, normally the full (inductive plus capacitive) range at nominal voltage, expressed as a percentage. VSC: Voltage Source Convertor, A forced commutated device (for example, IGBT) based self-commutated convertor that is capable of generating AC voltage from DC capacitor. Voltage/Current (V/I) Characteristic: The relationship between the current of the STATCOM and the voltage at the point of connection. Lagging Operation: Inductive operation or reactive power absorption of the STATCOM similar to a shunt reactor. Leading Operation: Capacitive operation or reactive power generation of the STATCOM similar to a shunt Capacitor. TSP: Transmission Service Provider C.2 Relevant Standard: STATCOM Station shall comply with the following standards (latest edition): Sl. Description Standards No. 1 Voltage source converter (VSC) IEC- 62927 valves for STATCOM IEEE- 1052 IEC-60747 2 Control, protection and IEC-61000 monitoring IEC-60255 [Insert Name of the SPV] 122 ……2026Transmission Service Agreement Sl. Description Standards No. 3 Valve Hall for housing the IEC-60071 equipment as above comprising IEC-60270 of: IEC-60137 - wall bushings for connection between converter phases and decoupling reactors, - piping and tubing connections of the cooling system to converter - connection of the control cabinet with the converter through optical fibers - internal lighting, auxiliary power supply (AC and DC) and power socket system - internal HVAC system 4 X kV, dry insulated, air core and IEC- 60076 air self-cooled decoupling reactors. Mechanically Switched Reactors (MSRs), half-reactors stacked on above the other, Outdoor installation, Complete with supporting structures 5 Power Capacitors (MSC etc.) IEC-60871- 1 6 400 kV Power transformer IEC-60076 (Coupling Transformer) IEC-60354 7 CT’s and VT’s IEC- 61869 8 Dis-connectors and Earthing IEC- 62271 Switches 9 HV and MV Circuit Breakers IEC- 62271 10 Surge Arresters IEC- 60099 11 Auxiliary and grounding IEC- 60076 transformer IEEE C57.32 IS- 5553 (Part 6) 12 Neutral Grounding Resistor, IEEE- charging resistor C57.32 13 UPS, SMPS and Other Power IEC- 62040 supply units IEC- 61558 14 Cyber Security IEC-62243 [Insert Name of the SPV] 123 ……2026Transmission Service Agreement C.3 Scope of work for STATCOM The scope of work with regard to the works associated with the STATCOM shall comprise ±300 MVAr Modular Multi-level Voltage Source Converter (MMC-VSC) based STATCOM along with 2x125 MVAr MSC (Mechanically Switched Capacitor). STATCOM can either be Single/ multiple units. The minimum size of a unit allowed is 150 – 200 MVAr. TSP shall ensure that there are no coordination issues between multiple STATCOM branches of STATCOM station. Further complete Dynamic range for STATCOM may also be installed based on appropriate studies instead of combination of VSC with MSC/MSR technology. MV bus voltage is to be decided by OEMs. The TSP shall be responsible for the complete installation of STATCOM station along with the substation works as specified in the complete scope of work. The TSP shall also perform the system studies (steady state and dynamic) according to the requirement mentioned and documentation of the same shall be preserved by TSP and to be submitted to CEA/CTU/GRID-INDIA, as per their request. TSP shall carry out a detailed study on prevailing system conditions before interconnection of the STATCOM to assess the performance of the STATCOM. Parameters tuning to avoid any adverse impact on the grid with integration of the STATCOM shall also be identified and implemented at this stage. TSP shall carry out tuning of Power Oscillation Damping (POD) along with an interaction study with nearby HVDC/FACTS controllers. TSP shall ensure interconnection study at the time of commissioning and shall also be responsible for tuning the POD during the license period as per relevant standards (e.g. IEEE 1052). The switchgear for connection of STATCOM units MSCs and MSRs provided on the secondary side of the coupling transformer shall be of standard voltage rating as per relevant IEC. The switchgear, structure, control, protection and substation automation on the 400 kV side shall be as per applicable Technical Specification of the substation equipment. Generally, the purpose of STATCOM is to improve system stability, provide damping, and smooth out the step voltage change associated with MSCs, MSRs and external compensating equipment (i.e. any existing capacitor and reactor banks) switching and provide steady state VARs as needed to support the 400 kV bus voltage. [Insert Name of the SPV] 124 ……2026Transmission Service Agreement In order to get optimum control of MVAr, the control of MSCs and MSRs, as well as reactor banks connected on the 400 kV HV side, may be integrated along with STATCOM control to provide steady state 400 kV bus voltage control in a smooth manner. MSRs and MSCs are to be switched to relieve the STATCOM from high level operation, reduce its continuous losses and maximize its dynamic control potential. There should be a provision for the independent operation of MSC/MSR after delinking it with STATCOM controls when STATCOM is out of service due to any reason. Switching of MSC/MSR shall be based on value of external bus voltage. The operating functions of the STATCOM Station shall include:  Steady state voltage control of 400 kV bus,  Balance steady state voltage at 400 kV bus,  Dynamic over-voltage control,  Transient and Dynamic stability control  Damping of Power Oscillations It is assumed that the arresters will limit any transient and switching surge over voltages and may also, by design, limit dynamic over voltages. The requirement of reactive power compensation (as defined above) guaranteed by the TSP shall not be less than the levels specified considering following.  The total cumulative Capacitive (+) and Inductive (-) MVAr rated Capacity of STATCOM Station as defined above comprising of STATCOM, MSCs (as applicable), MSRs (as applicable) coupling transformer, coupling reactor or any filter (if applicable) shall be rated at 1 p.u. voltage, for the frequency range of 48.5 Hz-50.5 Hz and at 50 o -C (Celsius) ambient temperature at 400 kV Bus (Referred to as “Point of Common Coupling” or PCC).  Capacity of one or more branches of MSC, MSR in STATCOM Station can be included in the STATCOM with equivalent capacity. Accordingly, ratings of STATCOM Unit/Branch equipment may be designed. Example of equivalent acceptable solutions for each STATCOM Station is given below: [Insert Name of the SPV] 125 ……2026Transmission Service Agreement For ±300 MVAr STATCOM: Option 1: ±300 MVAr STATCOM, 2x125 MVAr Mechanically switched Capacitor (MSC). Option 2: +425/-300 MVAr STATCOM, 1x125 MVAr Mechanically switched Capacitor (MSC). Option 3: +550/-300 MVAr STATCOM  The rated capability of STATCOM, MSC (as applicable) and MSR (as applicable) shall be at 400 kV (Referred to as “Point of Common Coupling” or PCC) and in the steady state frequency range of 48.5 Hz- 50.5 Hz.  The STATCOM Station including STATCOM Units, MSCs and MSRs shall be designed to operate continuously under the worst possible combination of steady state voltage range of 360-440 kV and frequency range of 47.5 Hz – 52.5 Hz respectively and transient and temporary over voltages defined in Clause C.6.1-f).  The AC voltage unbalance at fundamental frequency shall be assumed equivalent to a negative phase sequence component of 1.5% for equipment rating purposes.  The reactive power compensation levels shall be determined by manufacturing tolerances of the components and measurements carried out using metering accuracy instrumentation at the 400 kV feed points to the STATCOM Station.  The reactive power capability shall also be determined by calculations based on test values of appropriate quantities at the discretion of the owner. [Insert Name of the SPV] 126 ……2026Transmission Service Agreement  In calculations of capability and availability, the owner shall assume the most unfavorable combinations of control, manufacturing and measurement tolerances.  In case more than one STATCOM Station are installed in a particular substation, each STATCOM Station shall be connected to 400 kV bus individually with complete separate downstream system. Each individual STATCOM station shall have complete independent yet coordinated control system to avoid simultaneous tripping of both STATCOM Stations. The system shall be design in such a way that single common contingency (other than loss of 400 kV voltage, abnormal system events) will not cause tripping of both STATCOM Stations.  Operation of STATCOM Station shall not excite any resonance condition in connected Power System.  Control of STATCOM Station shall be designed to prevent hunting between MSRs, MSCs and STATCOM. C.3.1 STATCOM building The STATCOM station shall have an independent building including a separate control room different from the main control room building of the 765/400 kV Substation. The STATCOM Building shall comprise of following facilities: 1. Control and Relay Panel room 2. ACDB and DCDB room 3. Battery room 4. Service Room cum workshop 5. Conference room 6. Valve hall 7. Cooling system room 8. Lobby 9. Corridor with minimum width of 1600 mm 10. Portico 11. Common Toilet 12. Provision of shaft for electrical, sanitary, water supply facilities 13. Other facilities as per functional requirement of building [Insert Name of the SPV] 127 ……2026Transmission Service Agreement 14. AHU Room C.4 Ambient Condition STATCOM Station should be designed to perform at 50 °C ambient temperature. C.5 Power System Characteristic The following AC power system characteristics apply at the point of connection i.e. point of common coupling in this case (PCC). STATCOM station operation is required within the parameter value and duration given in following table: S. Power System Characteristic Value unit No 1. Nominal ac system voltage, line-to- 400 kV line 2. Maximum continuous ac system 420 kV voltage, line-to-line 3. Minimum continuous ac system 380 kV voltage, line-to-line 4. Maximum short-term ac system 448 kV voltage, line-to-line 5. Maximum duration of item 4 10 s 6. Continuous negative-sequence 1 % voltage component (used for performance calculation) 7. Continuous negative-sequence 1.5 % voltage component (used for rating calculation) 8. Continuous zero-sequence voltage 1 % component 9. Nominal ac system frequency 50 Hz [Insert Name of the SPV] 128 ……2026Transmission Service Agreement S. Power System Characteristic Value unit No 10. Maximum continuous ac system 50.5 Hz frequency (for rated output) 11. Minimum continuous ac system 48.5 Hz frequency (for rated output) 12. Maximum short-term ac system 52.5 Hz frequency 13. Minimum short-term ac system 47.5 Hz frequency 14. Basic Insulation Level (BIL) 1550 kV peak 15. Switching impulse level (SIL) 1050 kV peak 16. Power Frequency Withstand voltage 630 kV 17. Maximum three-phase fault current a) for performance requirements a) kA 63 b) for rating of STATCOM kA for b) 1s 63 X/R (Positive/Negative Seq)* X/R (Zero Seq)* 4 Clearing time - normal 5 s Clearing time – backup 0.1 s 0.75 18. Maximum three-phase fault current 63 kA 19. Minimum three-phase fault current # -for performance requirements 26 kA [Insert Name of the SPV] 129 ……2026Transmission Service Agreement S. Power System Characteristic Value unit No -for safe operation 26 kA 20. Maximum single-phase fault current 63 kA 21. Minimum single-phase fault current# 12 kA 22. Harmonic impedance sectors for Chapter 7.3 of CIGRE each harmonic number up to the Publication 139 49th harmonic or system impedance data as R-X values with frequency steps not larger than 1 Hz (for performance and/or STATCOM system component rating) 23. Background harmonic voltage (or 5th Harmonic 1.5% current) spectrum (for STATCOM 7th Harmonic 1.0% components rating) (Distortion up to 15th Harmonic Other Harmonics 0.5% (each) 24. Power System Phase Rotation CCW The STATCOMs shall remain connected to the grid and shall be able to operate at rated reactive power capability when voltage at the interconnection point, on single phase or three phases dips up to the level depicted by the thick lines in the following curve (for specified time) and up to at least 0.3 p. u. in case of two phase faults: VT : Actual Voltage; Vn: Nominal Voltage [Insert Name of the SPV] 130 ……2026Transmission Service Agreement [Insert Name of the SPV] 131 ……2026Transmission Service Agreement C.6 STATCOM Station Characteristics Figure-1: Conceptual Indicative Schematic diagram of STATCOM Station Figure-2: VI Curve of the VSC Portion [Insert Name of the SPV] 132 ……2026Transmission Service Agreement Figure-3: VI Curve of the STATCOM Station C.6.1 STATCOM Station Ratings The output of a STATCOM Station shall be adjusted continuously over the range illustrated in Figure-3. The following items define the ratings of the STATCOM station equipment. a) The STATCOM Station should regulate the voltage of 400 kV bus to a reference voltage of 400 kV (1.0 per unit, Point L Figure-3), continuously adjustable between 0.95 per unit and 1.05 per unit. b) The nominal capacitive and inductive reactive power output of the STATCOM should be as defined in the scope, at 1.0 p.u. AC bus voltage and nominal system frequency (f), and 50°C ambient temperature (Point A and point B of figure-2). c) The slope of the STATCOM Station characteristic should be adjustable in steps of not greater than 0.5% between 1% and 8%, on a basis of cumulative MVA capacity of STATCOM Station (A+B in Figure-3). d) The STATCOM Stations shall continue to inject reactive power during temporary under voltage down to 60 kV (0.15 p.u. for the duration 0.3 sec (Point C) and STATCOM behavior for voltages above 0.15 p.u. shall be as specified under section C.5 above, The STATCOM system may be blocked if the under voltage persists for time beyond limits specified under section C.5 above. [Insert Name of the SPV] 133 ……2026Transmission Service Agreement e) The STATCOM shall continue to absorb reactive power during HVRT Conditions in a controlled manner as per the following. Minimum time for remaining connected to the Nominal Voltage (pu) Grid V > 1.50 Instantaneous trip 1.50 ≥ V > 1.30 100 milli seconds 1.30 ≥ V > 1.10 10 seconds V ≤ 1.10 Continuous STATCOM Station may be tripped if the respective temporary over voltages as mentioned above persists for more than its respective mentioned duration. f) The STATCOM Station should be capable of repeating temporary operation as defined in any one of item (d) and (e) as above for at least 3 charging cycles in 60 mins. g) The coupling transformer and all bus equipment, such as filter branches (if applicable), MSC and MSR branches etc. and the MV Bus should be rated to withstand the specified continuous and short-term operation, and to withstand or be protected against voltage and current stresses that exceed these conditions. h) All equipment in the STATCOM Station should be capable of sustaining, without damage, any fault limited by the maximum design short circuit level of the system and the Coupling transformer impedance. i) The TSP shall assume the negative sequence voltage of 1% at rated short circuit level and provide control to reduce this unbalance. j) The injected harmonics by STATCOM Station under the full operating range measured at 400 kV Bus (PCC) in accordance with IEEE standard. k) The STATCOM controls should be designed to correct negative sequence voltage during steady state operation. l) The switching module design should include an appropriate allowance for stray capacitance and component tolerances. m) The STATCOM should be designed to prevent, or alternatively to withstand, false firing events, i.e., the firing of any valve at an incorrect time in the cycle or when not ordered. [Insert Name of the SPV] 134 ……2026Transmission Service Agreement C.6.2 Control Objectives The control system shall control the STATCOM, MSCs, MSRs required under this specification, as well as all bus reactors on the 400 kV HV bus of the substation. Operation logic for the breakers, disconnectors and earth-switches in the STATCOM Station shall also be incorporated in the control system. The control shall be programmable and shall have sufficient scope and flexibility (software programming margin of at least 20%) to permit re-programming according to future changes/addition in the power system. The operator interface must be integrated in a latest version of Windows environment. C.6.2.1 STATCOM Station Functions and Applications C.6.2.1.1 Voltage Control mode (Automatic and Manual) Control of the positive sequence component of the fundamental frequency voltage in steady state at POI shall be, with slope in the range as specified at clause 6.1 (c) above. There shall be following provisions in STATCOM System to operate in Voltage Control Mode: a) To adjust the reference voltage for changes by Grid Operator. b) To adjust the value of reactive power drop in p.u. to provide a stable, coordinated and dynamic response. c) To adjust the voltage dead band with a minimum magnitude of ±0.05 p.u. C.6.2.1.2 Fixed Reactive Power Mode In this mode, the STATCOM system shall maintain a specified constant reactive power output at the POI under continuous / steady state operating region. The target reactive power level and mode (injection or absorption) shall be specified by the Grid operator. There shall be a provision to adjust the reactive power set point. The dynamic response of the STATCOM system to any changes in reactive power shall be positively damped with a damping ratio of 0.3 or better. C.6.2.1.3 Steady State Condition The STATCOM Station (STATCOM along with MSCs and MSRs) shall provide necessary reactive power support to the 400 kV bus (PCC) to compensate for voltage variation under steady state. [Insert Name of the SPV] 135 ……2026Transmission Service Agreement C.6.2.1.4 Dynamic Over-voltage Control Performance The STATCOM shall be required to provide necessary reactive power support with fast and smooth variation so that over-voltages under dynamic conditions are controlled. STATCOM shall smooth out the step caused by the switching of MSCs and MSRs. The operation of each STATCOM over its range of MVAr from full capacitive to full Inductive capacity and vice-versa shall be on the basis of smooth variation. C.6.2.1.5 Transient and Dynamic Stability Performances The STATCOM Station shall provide necessary reactive power so that the transient and dynamic stability of the Owner’s system is enhanced. C.6.2.1.6 Damping of Power Oscillations The STATCOM shall provide necessary damping to power oscillations by modulating its output in its entire range based on the measured rate of change of power/frequency at the 400 kV bus. The damping controller would track local area oscillations as well as wide area oscillations and control would include several loops each focused on different frequencies. TSP shall ensure the damping of oscillation during the entire license period including the pre–commissioning period as per relevant standards. (e.g. IEEE 1052). C.6.2.1.7 Facility for compensation of phase imbalance Provide negative phase sequence voltage control to minimize the presence of negative sequence content of the 400 kV bus voltage. C.6.2.1.8 Start up and Initial Switching The operation of STATCOM Station during start-up/initial switching on should not create significant energizing transients causing voltage drop, voltage distortion and swinging of transmission voltage angle at the PCC bus by more than +/-5%. TSP shall have to ensure this analytically during the design phase and also in the field after the commissioning of the facility. TSP shall prepare the design documentation and the same shall be preserved by TSP and to be submitted to CEA/CTU/GRID-INDIA, as per their requirement. C.6.2.1.9 Gain Supervision and Control To control the regulator gain in order to prevent oscillations and excessive overshoot in the STATCOM response, a gain supervision function shall be [Insert Name of the SPV] 136 ……2026Transmission Service Agreement implemented. This shall be an essential function for the supervision of stability of closed-loop voltage control. The function of this controller is that when the supervision of the gain in the voltage regulator detects oscillations in the voltage controller output, the gain shall gradually be reduced until stability is reached. Normally it is a changed condition in the transmission system contribution to the closed loop gain that results in instability. The reduction in the voltage regulator gain shall only balance the external change. The control should be adaptive in order to maximize its effectiveness. Gain reductions should be indicated and the reduction of the gain shall be able to be reset to nominal value by means of commands from the operator interface or automatically. A relative gain factor shall also be able to be changed from a gain optimizer. C.6.2.1.10 Coordinated reactive power control of external devices To optimize the use of dynamic VARs versus steady state VARs, control of externally connected shunt capacitor or reactor banks shall be implemented. Such banks will be connected locally to a HV bus or/and at MV bus. For simultaneous control with the supplementary VSC current controller, coordination for the two functions shall be provided. External devices like mechanically switched capacitors (MSC)/mechanically switched reactors (MSR) can be switched ON or OFF to position the steady state operating point of the VSC so as to extend its dynamic range. There should be a provision for independent operation of MSC/MSR after delinking it with STATCOM controls when STATCOM is out of service due to any reason. The threshold values for switching the MSC/MSR on/off shall be configurable in all modes of operation. C.6.2.1.11 Supplementary VSC current controller To optimize the use of dynamic VARs versus steady state VARs, a control function that slowly reduces or offsets the STATCOM point of operation shall be implemented. By deliberately adjusting the voltage reference setting within a narrow window the STATCOM system output is pushed towards either a specific point or towards a window to preserve dynamic range. This slow operating function is meant to provide for slower controllers, such as externally connected shunt banks to operate and meet the slower long term voltage variations caused by daily or weekly load variations. Rapid changes in the system voltage that call for dynamic compensation will have priority over this type of controller. C.6.2.1.12 Gain optimization To provide operation at optimal regulator gain, a fully automatic optimizing function shall be implemented. This function operates by inducing a small [Insert Name of the SPV] 137 ……2026Transmission Service Agreement change in the STATCOM output. The gain is adjusted based on the network response signal. C.6.2.1.13 Control of Direct Current During STATCOM operations, any flow of direct current to the transformer’s MV side must be less than 25% of the transformer magnetizing current. DC current flow in the transformer should be minimized by an independent control function that minimizes DC current. For presence of up to 0.2% second harmonic in 400 kV system, the STATCOM control should minimize DC current flow in the transformer. C.6.2.2 Under Voltage Strategy It is essential that the STATCOM Station operates in a robust manner when transmission system under voltages appears. In case of single phase or three phase faults, the STATCOM units must operate unrestricted, producing its rated capacitive current for transmission system voltages down to 0.15 p.u.. In case of two phase fault, the STATCOM shall be capable to produce rated capacitive current atleast down to 0.3 p.u., however, it shall be designed to operate upto 0.15 p.u. The STATCOM must be designed to operate at transmission system under voltage, even considering that severe voltage unbalances can appear. The STATCOM must not be restricted by short term negative sequence voltages up to 1.5%, appearing in conjunction with under voltages. Transmission system under voltages below 0.15 p.u. will appear in conjunction with transmission system faults. The STATCOM must ride through during faults and post fault under voltages. The minimum trip delay for the STATCOM Station, upon complete loss of the transmission system voltage shall not be less than 5 seconds. If station AC auxiliary power distribution is affected, critical loads must be fed from DC station batteries, uninterrupted power supply (UPS) without tripping the STATCOM Station. Adequate capacity must be kept in DC station batteries, UPS to feed critical loads for the smooth operation of the STATCOM Station facility. There must be redundant station battery system with each station battery system capable of delivering 100% load. At under voltage conditions for the transmission system voltage, special control strategies are activated which override the normal control modes presented above. Normally if the voltage is low, the output from the STATCOM will be capacitive. If the voltage in all three phases goes below a level, but not greater than 0.15 p.u., a special under voltage strategy may be [Insert Name of the SPV] 138 ……2026Transmission Service Agreement activated that controls the STATCOM output to 0 MVAr. As soon as the voltage goes higher than 0.15 p.u., the under voltage strategy is deactivated and the normal control will be in operation (for the specified duration). The STATCOM Station must not be tripped or shut down automatically due to under voltages appearing for specified duration as specified under section C.5 above. STATCOM Station must continue to operate when AC system Voltage on any or all phases dips down to 0.15 p.u. voltage as per the characteristic given at section C.5. C.6.2.3 Over Voltage Strategy C.6.2.3.1 The TSP shall carry out dynamic stability study upfront in order to assess the dynamic overvoltage requirements. These studies shall include conditions with maximum and minimum short circuit system MVA conditions, single phase and three phase faults as well as stuck breaker, outage of the nearby generator and also with the outage of parts of the STATCOM Station. It is important that the STATCOM Station rides through temporary over voltages and not trip when it is needed the most. C.6.2.3.2 The system should be able to withstand any 3 phase, 5 cycle (100 ms) and single phase 10 cycles (200 ms) fault with consequent loss of a 400 kV double circuit line and loss of a 500 MW generator. The fault duration mentioned above corresponds to time assumed for the persistence of fault. For other system parameters refer clause 5 above (Power System Characteristics). In addition to above requirement, system contingency cases as provided in Annexure-I need to be considered and satisfied. C.6.2.3.3 The 400 kV system and equipment to which the STATCOM Station is connected is designed to withstand switching surge overvoltage up to 2.5 p.u. and power frequency over voltages up to 1.5 p.u. with initial value of the temporary overvoltage up to 2.0 p.u. for 1-2 cycles. Based on arrestor coordination and under the worst case scenario the 400 kV system phase to ground peak over voltages may be expected as follows i) 650 kVp for 3 peaks ii) 575 kVp up to 5 cycles iii) 530 kVp up to 1 second iv) 475 kVp up to 10 seconds a) The STATCOM Station shall be designed to withstand these sequential over voltages. [Insert Name of the SPV] 139 ……2026Transmission Service Agreement b) If the over voltages greater than 1.1 p.u. are exceeded in magnitude and duration due to any system contingencies, suitable control action shall be taken by STATCOM Station to bear this kind of contingency. c) The TSP shall evolve the insulation co-ordination of the components of the STATCOM Station after studies have been conducted to determine the over- voltage profile with the STATCOM connected to the system. d) The TSP shall ensure that STATCOM Station will not excite ferro-resonance and sub-synchronous oscillation in the AC system. The study report in this regard shall be preserved and to be submitted to CEA/CTU/GRID-INDIA, if required. e) It may also be noted that the tripping action for 400 kV lines is initiated if the overvoltage exceeds 1.1 p.u. for 10 seconds. The tripping of 400 kV lines is initiated if 1.5 p.u. voltage persists for more than 100 milli seconds. The over voltage strategy shall be coordinated with these settings such that the STATCOM Station rides through up to these levels. C.6.2.4 STATCOM Station Over load / Over Current The overvoltage cycles mentioned in clause 6.2.3.3 above create a corresponding current overload in the STATCOM Station components; the STATCOM Station and its components shall be designed to withstand these. In addition to the above the STATCOM Station and its components shall be designed to withstand overloading caused due to the following eventualities. i) Short circuits and ground faults in the 400 kV system especially those occurring near the STATCOM Station and medium voltage bus of the STATCOM Station. ii) Transient overvoltage due to switching operations and atmospheric effects. iii) Temporary over voltages. iv) Short circuits in the transformer secondary circuit such as:  Bushing terminal fault  Flashover across a reactor, Bus Bar and other connected components/switchgear etc. v) Protection system faults. If the rated overvoltage is exceeded as a result of prolonged stressing or for other reasons, the protection specified elsewhere in the specification shall come into effect to prevent damage. C.6.2.5 Dynamic Performance Controls of STATCOM Station [Insert Name of the SPV] 140 ……2026Transmission Service Agreement The TSP must describe in detail, the dynamic reactive power controls for enhancing stability margin and also damp oscillations of any critical frequencies. The dead band for continuous damping control must be very small so that there are no discernible sustained oscillations. C.6.2.6 Protective Control Functions TSP shall provide all necessary protections including Main and Back-up protections for all protective zones and equipment like transformers, STATCOM Units, MSCs (if applicable), MSRs (if applicable), MV Bus Bar etc. TSP shall provide any protective control functions to meet the performance requirement of STATCOM under the scope of the TSP. a) Overvoltage Protection TSP shall provide adequate overvoltage protection as a result of any normal operation, mal-operation or system event. b) Over current Protection TSP shall provide adequate over-current protection for the STATCOM Station as a result of any abnormal operation, mal-operation or system event. c) Gate level control Supervision TSP shall provide adequate Sub module Gate level control supervision. C.6.2.7 STATCOM Station Response STATCOM station response shall be such that the change in measured system voltage to small disturbance should reach 90% of the desired total change within 30 ms of initiating a 5% step change of voltage reference. The maximum overshoot should not exceed 120% of the total change and the settling time should not exceed 100 ms, after which the voltage should be within ±5% of the final value. This response characteristic within these limits must be respected when the system’s three-phase fault MVA is between the minimum and maximum value defined in clause-5. The response of the system voltage using the actual controller should be validated on a real time simulator during the Factory Acceptance Test (FAT) at the manufacturer’s premises. For the purpose of STATCOM Station, response time measurement and signal conversion of the voltage, the error should not exceed 0.3%. The voltage response acquisition circuit should have a response time of no longer than 10 ms. However, time longer than 10 ms can be allowed provided the requirement of STATCOM response time is met. [Insert Name of the SPV] 141 ……2026Transmission Service Agreement Figure-4 Response and Settling time C.6.3 Harmonic performance and AC harmonic filter design It is likely that with multi-level VSC based technology, no filters or only a small high-pass filter will be needed. The STATCOM shall be operable without AC filters. The STATCOM Station should be designed to eliminate the effects of any harmonic resonance between its MSRs, MSCs banks, filter branches, and the AC system. To limit the harmonic distortion imposed on the 400 kV transmission system, the additional contribution of harmonic distortion from the STATCOM Station to 400 kV system (PCC) should not exceed 1% for the total and 0.5% for any specific harmonic. C.6.3.1 Filter performance The distortion levels as specified should be met for the following: a) The continuous range of all system and environmental conditions. b) Variation in total filter capacitance due to manufacturing tolerance, ambient temperature, aging, and changes in capacitance up to alarm level. c) Variation in tolerance for STATCOM parameters, such as transformer winding unbalances, valve firing variations MSC and MSR unequal reactor and capacitor reactance between phases. d) System frequency in the range of 48.5 Hz to 50.5 Hz. Calculation should take into account all possible combinations of STATCOMs, MSCs and MSRs. C.6.3.2 Filter component rating The harmonic filter components (and other STATCOM components) should be rated to carry continuously the harmonic currents caused by the background harmonic distortion of the system and the harmonic currents [Insert Name of the SPV] 142 ……2026Transmission Service Agreement produced by the STATCOM itself. Unless otherwise specified, harmonic currents from the system and the STATCOM of the same order should be added arithmetically. All filter harmonic currents of different order should be added quadratically (root sum of squares). The rated voltage of capacitors should be derived from the largest arithmetic sum of the power-frequency and individual harmonic voltages obtained from stress calculations in continuous operating conditions (Note: Maximum fundamental voltage and maximum harmonic contributions may not exist at the same time for STATCOM configurations including MSRs or MSCs). For filter capacitor voltage rating, the loss of capacitor unit or elements should be considered up to the trip level. The rated voltage of so-called "low voltage" capacitors (e.g. in double or triple tuned filters) should be chosen such as to also withstand imposed transient stresses from faults, energization, or other switching events. C.6.3.3 Harmonic at PCC The STATCOM Station’s contribution to the harmonic distortion levels at the STATCOM Station connection point (PCC) to the transmission system shall not exceed the limits defined in IEEE-2800 standard. C.6.3.4 Harmonic calculation: Chapter 7.3 of CIGRE Publication 139 together with information in PSSE network files given shall be used for the Network harmonic impedance. C.6.4 MV Switchyard • Medium Voltage (MV) delta bus shall be grounded through a Grounding Transformer (i.e. zig-zag winding Transformer) along with a suitable resistor in the neutral. • MV Switchyard of different STATCOM Station branches shall be fenced with a fence height of three (3) meter. To minimize the probability of electrical fault suitable arrangement i.e. electrified fence shall be done to prevent the encroachment of unwanted animals or other to minimize the probability of electrical faults (Ph-E, Ph-Ph). Further bus bar arrangements shall be made in a way to minimize the probability of electrical faults. • Secondary side of the Coupling Transformer shall be provided with suitable surge capacitors to mitigate transfer surges. [Insert Name of the SPV] 143 ……2026Transmission Service Agreement • For MV bus bar, an Aluminum conductor (Tube, Rectangular Hollow Section or C Section) may be used, however, a suitable bus bar end cover/cap shall be provided to avoid any animal/bird entering the hollow space. C.6.5 Broadband Interference C.6.5.1 Radio Interference The TSP shall take necessary precautions in the form of shielding of valve hall and building or Containers to meet its own requirement together with any requirements that may be specified in Section-Project. Further, the following requirements shall also be met: a) With the STATCOM Station operating at any load upto rated value and within the design range of firing angle, the radio interference level from electromagnetic or electrostatic inductions generated by the STATCOM station shall not exceed 100 micro-volts/m, under fair weather conditions, at 500 m away from STATCOM fence or boundary of the substation whichever is higher. The Radio Interference Level (RIL) criteria shall be achieved at all frequencies within the range of 150 kHz to 300 MHz and with the STATCOM operation at any level up to and including rated value, the design shall provide correcting measures, in case the specified design not being realized in the final installation. In case of any third-party complaints about the radio interference, suitable measures shall be implemented by the TSP. b) Measurements of actual RI at STATCOM Station shall be made by the TSP, at points along the above defined contour and at other critical points. c) RIV (Radio Interference voltage) measured at a phase to ground voltage (266 kV rms) in accordance to NEMA-107 shall not be more than 500 micro-volts for 400 kV system. For other system voltages, IEC/NEMA in the order of preference shall be applicable. C.6.5.2 Interference with Power Line carrier and open wire carrier system The TSP shall take the necessary precautions in the form of noise suppression techniques and filtering devices to prevent harmful interferences from STATCOM Station to the power line carrier communication (PLCC) system operating on connected AC transmission network. The frequency spectra to be protected are: System Frequency spectrum Power Line Carrier 30 kHz to 500 kHz [Insert Name of the SPV] 144 ……2026Transmission Service Agreement Open Wire Carrier 5 kHz to 30 kHz C.6.6 Audible Noise The TSP shall limit the audible noise in various areas of the STATCOM Station buildings and containers to the following values. Valve hall (Inside) 90 dBA Mechanical equipment areas indoor (measured at 2 75 meter distance) dBA Mechanical equipment outdoor (Measured at 15 m 75 distance) dBA Control Room Building* 60 dBA At the limits of the STATCOM STATION perimeter fence 80 dBA *This is the background noise from the ventilation system in adjacent rooms, control cubicles etc. Printers, recorders may be switched off during the measurement. C.6.7 Loss Requirements C.6.7.1 The TSP must guarantee the total losses of STATCOM Station, be less than 1% of the reactive power output individually at its inductive limit (STATCOM+MSRs) and capacitive limit (STATCOM+MSCs) for the cumulative highest reactive power output of STATCOM Station at PCC with the worse combination of manufacturing tolerances for the option - 1 to 2 as provided in clause C.3. In case of Option 3 as provided in clause C.3 i.e. +550/-300 MVAr STATCOM without MSC and MSR, the TSP must guarantee the total losses of STATCOM Station will be less than 1.5% of the reactive power output individually at its inductive limit and capacitive limit for the cumulative highest reactive power output of STATCOM Station at PCC with the worse combination of manufacturing tolerances..For the purpose of total loss measurements, it should be assumed that the ambient temperature is 20 °C, the PCC voltage is 1 per unit, and the slope setting is 1%. The STATCOM system may not operate under these conditions, but they provide a common base. [Insert Name of the SPV] 145 ……2026Transmission Service Agreement C.6.7.2 The total losses shall include all components, as well as different parts or subsystems of the complete STATCOM Station such as coupling transformer, All VSC systems and components, MSC and MSR, Control and protection systems, including ancillary devices such as HMI, fault recorders, and SCADA, Auxiliary Power supply systems, cooling systems, Building ancillary services such as lighting, air conditioning, heating, and ventilation. It may be noted that for the redundant VSC valve levels and dual/redundant control and protection systems, the losses of redundant VSC valve levels and dual control and protection systems shall be considered during loss measurement. C.6.7.3 For the dual or redundant systems design of STATCOM Station, such as dual pumps or redundant fans, dual systems losses are to be excluded, if the dual system is not in service during the normal operation of the STATCOM Station. However, dual systems should be included if they are required to be in service under the defined operating conditions. The same methodology shall be applied for HVAC (heating ventilation and air conditioning systems). C.6.7.4 The TSP is required to prepare documentation for the detailed calculation of total losses based on measurement during Factory Acceptance Tests of major equipment and systems mentioned above as per relevant IS/IEC/IEEE standards and the same shall be preserved and to be submitted to CEA/CTU/GRID-INDIA, as per their requirement. Further for equipment/systems, whose loss measurement cannot be done during Factory Acceptance Test, the same can be measured at the site, and a combination of calculation and measurement shall be used to derive the total losses as specified above. During Loss measurement, all fans, and pumps; valve room and control room air-conditioning system shall be switched on. However, redundant fans, pumps and air-conditioners shall be kept off during loss measurement. C.6.7.5 During the factory tests the losses for the following equipment shall be measured/ assessed as detailed below: Coupling transformer: Losses shall be measured at factory/lab at the maximum rating, at power frequency as per relevant IEC/IS under below mentioned conditions: i. No load loss (Iron loss) at rated voltage and fundamental frequency. ii. Load loss (copper loss) at rating corresponding to maximum continuous current and at 75 °C. iii. Transformer cooling equipment’s loss (Auxiliary loss) at rated voltage and fundamental frequency. Reactors: [Insert Name of the SPV] 146 ……2026Transmission Service Agreement The losses shall be measured at the factory/lab at the maximum rating at power frequency as per relevant IEC/IS. VSC Valves: Converter losses comprise the losses in power electronic switches [insulated gate bipolar transistor (IGBT) or equivalent], made up of conduction and switching losses, and the losses in DC capacitors, resistors, and inductors used within the converter system. Refer IEEE-1052 for calculating VSC losses. Capacitor: The capacitor losses shall be measured at the manufacturer’s works at power frequency as well as calculated to obtain the losses in the complete bank on the basis of factory measurement. Auxiliary System: Auxiliary. power losses shall be calculated from the kW and efficiency of all motors (name plate rating) of the cooling system, air conditioning, ventilation etc. The higher of the total losses for the entire auxiliary systems occurring at full capacitive capacity MVAr or full Inductive MVAr as the case may be shall be considered for arriving at the total losses. Harmonic Filters, if any: The losses shall be calculated at the maximum STATCOM Station loading at 400 kV and 50 Hz. The calculations shall be on the basis of the tested results of the components. C.6.8 Selection of Insulation Levels C.6.8.1 Arresters: Protective levels of arresters connected to the 400 kV AC Bus Bars of the STATCOM Station shall be coordinated with the insulation and surge arrester Characteristics of the 400 kV AC systems to which the STATCOM Station is to be connected. The specification and characteristics of the surge arresters installed in 400 kV AC system is given in the Substation specifications. The front of wave (FWWL), lightning impulse (LIWL) and switching impulse withstand levels (SIWL) shall be determined by the following margins: a) A SIWL at least 1.15 times the switching impulse protection level. b) A LIWL which is an IEC standard level corresponding to the SIWL and shall be at least 1.25 times the lightning impulse protection level. [Insert Name of the SPV] 147 ……2026Transmission Service Agreement c) A FWWL which is at least 1.25 times the front of wave protection level. In addition to the above minimum basic requirement, the various insulation level of 400 kV equipment shall be as below. The STATCOM Station equipment, coupling transformers etc. shall be co-ordinated accordingly. Description SIWL LIWL All equipment other than Transformer 1050 1425 Bushing and winding kVp kVp Transformer Winding 1175 1425 kVp kVp Transformer Bushing 1175 1550 kVp kVp C.6.8.2 Valves The requirement of insulation levels of the valves shall be as per the design requirement. C.6.8.3 Air clearances The air clearances shall be determined by the TSP based on the required withstand levels for all waveforms in order to limit the probability of flashover within the STATCOM Station to a target value of one flashover in 15 years. C.6.8.4 Switchyard The air clearances for switchyard equipment shall be equal to or greater than the minimum values as specified in IEC-60071. Altitude correction factor (if any) shall also be considered as per IEC. C.6.8.5 Leakage distances The Creepage/leakage distance across insulation shall be determined by the TSP and shall be adequate to ensure that under conditions of heavy pollution, the probability of a flashover of an insulator does not exceed one in 15 years. However, the leakage distance for all AC insulators for outdoor installation shall not be less than 31 mm/kV of the maximum operating phase to earth rms voltage at the insulator. The leakage distance of equipment connected to 400 kV systems shall not be less than 13020 mm. [Insert Name of the SPV] 148 ……2026Transmission Service Agreement Specific creepage distance for outdoor bushings, insulator strings and long rod insulators shall be a minimum 31 mm/kV. C.6.9 STATCOM Station availability and reliability The following definitions apply: C.6.9.1 Outage terms: a) Outage The stage in which equipment is unavailable for normal operation due to an event directly related to the equipment which results in a reduction in STATCOM Station capacity. b) Scheduled Outage An outage that can be scheduled at least one week in advance. c) Forced outage The stage in which the equipment is unavailable for normal operation but is not in the scheduled outage stage and which results in a reduction in STATCOM Station capacity i.e. an outage which is not scheduled outage. C.6.9.2 Capacity terms Maximum Continuous Capacity (Pm) The maximum STATCOM Station capacity (MVAr) for which continuous operation under normal conditions is possible. C.6.9.3 Outage duration terms Actual outage duration (AOD) The time elapsed in hours between the start and end of an outage. C.6.9.4 Time Categories a) The number of hours in the reporting period in a full year, the period year is 8760 hours. If the equipment is commissioned, part way through a year, the period hours will be proportionately less than 8760 hours. b) Total Outage hour (TOH) The sum of all outage duration within the reporting period. TOH = AOD C.6.9.5 Availability and Reliability Terms Unavailability: [Insert Name of the SPV] 149 ……2026Transmission Service Agreement Unavailability is the duration for which the STATCOM Station is not available with a specified rating due to forced outages per year. If part of the station is unavailable, then the unavailability duration shall be counted proportionally. However, if STATCOM is out then its duration shall count as a fully unavailable STATCOM Station. However, If the STATCOM unit is out then the STATCOM Station unavailability shall be counted proportionally to STATCOM capacity. STATCOM Station Control system outage shall count as full STATCOM Station unavailability. ‘OF’ is the Outage Frequency which will be the number of forced outages per year. The period basis for availability and reliability calculations shall be 12 months. The TSP shall ensure that the design will meet the specified guaranteed and design target value of availability and reliability. Outage times for repair, maintenance and replacement of components shall be based on the premise that all items in the list of recommended spare parts are on hand, and that all maintenance schedules of recommended maintenance are adhered to. Reliability calculations shall be made and shall be presented as the expected frequency of unscheduled loss of STATCOM Station capacity. For simultaneous occurrence of events, for either of which a loss of capacity would result, the longer repair time shall be counted. The facilities shall be assumed to be utilized 100% of the time at 100% load, regardless of the actual reactive power generated/absorbed by the STATCOM Station. Hence the availability and reliability assessment will be based on the capability of STATCOM Station to generate/absorb the rated reactive power regardless of whether, it is in service or not. C.6.9.6 Availability Requirement The calculated availability of the system considered on an annual basis shall be equal to or exceed the following target values. Minimum availability requirement of each complete STATCOM Station  Guaranteed for STATCOM Station - 98% The outages of STATCOM Station capacity caused by the failure of equipment outside the scope of the TSP shall not be considered for the calculation of availability and reliability guarantee. However, such outages shall be restricted to 1) Complete loss to 400 kV supply (at PCC) [Insert Name of the SPV] 150 ……2026Transmission Service Agreement 2) Human Error. Circumstances causing curtailment of STATCOM Station capacity that will be included in reliability and availability assessment and which can lead to forced outages shall include but not be limited to the following: a) Failure of equipment b) Mal-operation of control and protection system c) Failure to start d) Reduction in capacity. C.6.9.7 Reliability Requirement a) Reliability In the assessment of reliability, the following events shall also be considered to constitute a STATCOM Station outage: i) A STATCOM Station shut down. ii) A reduction of STATCOM Station capacity due to an outage of any component of STATCOM Station The calculated reliability of the complete STATCOM Station shall be equal to or exceed the following design target values. The average outage frequency per year for each STATCOM Station shall not exceed the following values: Design target for Max acceptable STATCOM Station Guaranteed value for STATCOM Station Total Number of 3 x Nos. of 5 x Nos. of Forced Outages STATCOM STATCOM Station Station C.6.9.8 GUARANTEED FAILURE RATE OF Sub-modules. (Including all components and electronic). The maximum annual guaranteed failure rate of sub module (including all components and electronic) shall not exceed 1.0% per [Insert Name of the SPV] 151 ……2026Transmission Service Agreement STATCOM. The failure rate shall not include failures directly attributable to operation and maintenance errors. C.6.9.9 GUARANTEED VALUE OF FAILURE RATE OF AC POWER CAPACITOR The maximum guaranteed annual capacitor failure rate shall not exceed 0.15% except for first unit failure. The capacitor shall be considered as failed if its Capacitance value varies more than ±5% of the (actually measured) name plate value. Leakage of oil from the capacitor and the deformation of the capacitor unit shall be considered as a failure even if the capacitance value is within the tolerance limits. C.7 Design Principles The objective for the design of the STATCOM Station shall be to achieve a high level of availability and reliability as specified. Special attention shall be given to designing the STATCOM Station to avoid forced outages. The TSP shall conduct thorough design reviews to ensure the minimum risk of such outages. The TSP shall give careful attention to related factors affecting STATCOM Station performance such as subsystem and system testing, protective relays co-ordination and proper setting of relays. Except where greater reliability requirements are specified in these specifications, the design basis for STATCOM Station shall be such that no single contingency downstream from the medium voltage bus shall cause a total outage of the STATCOM Station. The following general criteria shall be followed for the design of the control system: a) Use of components similar to those whose reliability has already been proved in use. b) Use of good design practices, surge protection, filtering, and interference buffers to assure immunity to sensitive components and circuits against damage and interference by induced voltages and currents in the external cabling and cubicle wiring. c) Use of fail-safe and self-checking design features. d) Use of component and equipment redundancy, by means of either duplication or triplication with automatic transfer facilities wherever necessary to meet the requirement of these specifications. e) Design which in the event of component failures, provides for transfer to a less complex operating mode. f) Provision of alarm, fault diagnosis and indication [Insert Name of the SPV] 152 ……2026Transmission Service Agreement C.8 STATCOM Station Main Components C.8.1 STATCOM Unit The main electrical data of the STATCOM Units are the following: o Rated voltage 20 kV Minimum o Rated frequency 50 Hz o Redundancy (Sub Module) 2 Nos. or 5% whichever is higher o Rated Power of each STATCOM unit/Branch 50 MVAr Minimum o Valve Cooling Deionized/Demineralized water In general, the STATCOM units shall equally share the load however under contingency conditions it should be possible to run the units with unequal load. Charging of the DC capacitors of Sub module during the initial start-up shall be achieved by means of Resistors and bypass breaker arrangement. The charging resistor for DC capacitor of the STATCOM Sub module should be designed for three charges per hour followed by the appropriate cooling time. Power for the gate level control shall be derived internally from Sub module. The offered STATCOM Units with their Control system shall be suitably located inside the STATCOM Station Building. C.8.1.1 STATCOM Valve The valve shall be designed to meet the performance requirements described in this specification and as described below. In order to ensure a modern low loss and reliable solution, the STATCOM valve assembly shall use the multi-module (including redundant sub- modules) approach. The valves shall be designed to ensure satisfactory operation according to the overall performance requirements and include all necessary auxiliary equipment required for smooth and reliable operation. The valves shall be indoor air-insulated and cooled by de-mineralized water. The valves shall be of modular design and have removable Sub-Module for ease of maintenance. The valves shall be mounted to allow easy access for visual inspection, routine maintenance and replacement, and facilities shall be provided to enable easy access. C.8.1.2 Semiconductor Switches [Insert Name of the SPV] 153 ……2026Transmission Service Agreement The electronic switches should be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The valve shall be designed with individual semiconductor switches applied in a conservative manner with regard to their basic design parameters. The semiconductor switch shall meet the requirements of IEC 60747 except where otherwise specified herein. The semiconductor switches shall be designed to withstand all stresses expected under steady state, transient and temporary overvoltage conditions. Basic semiconductor devices shall be of the Press Pack type, or packaged to provide short circuit means in case of device failure such that the STATCOM can continue to operate without interruption. The adjacent sub-module should be protected against the possible explosion of the semiconductor switch. Under the restriction of redundancy (minimum two or 5% whichever is higher) i.e. the failure of any semiconductor switch or sub module or monitoring device etc shall not prevent continued system operation. In the event of any of the above failures, the STATCOM shall annunciate and identify the specific location of the failed device and continue operation until such time as repairs can be scheduled. During such time till the next shutdown can be availed, the STATCOM must continue to operate without downgrading STATCOM capability. The switching device’s design should include an appropriate allowance for unequal voltage distribution across individual devices in the valve due to the stray capacitor and component tolerances. Each switching device should be able to operate within component ratings, generally with at least two failed sub-module or levels. The number of possible failed sub-modules or levels as specified shall be consistent with the availability requirements of the STATCOM system. C.8.1.3 Sub module for Multi-Module Topology The key element of the multi-module topology shall be the sub-module. By increasing the number of these sub-modules, it is possible to obtain high voltage with extremely low harmonic distortion and very low dv/dt using a low switching frequency that reduces power losses. Sub-module shall have the following characteristics: VSC sub-modules should be protected against over voltages with appropriate strategies. A description of the failure mode of the switching device and the strategies used for failure should be provided. [Insert Name of the SPV] 154 ……2026Transmission Service Agreement In each fiber optic cable (having multiple fiber cores) used for control/communication purposes of sub-module at least two fiber cores shall remain available as spare for future use. C.8.1.4 The STATCOM sub-module has DC capacitors that require a charge to allow full functionality and performance. At the startup of the STATCOM Station, the capacitors are discharged. During the energization sequence of the STATCOM, Capacitors are charged from the main power grid via resistor operated in series to the main connection circuits. Once the desired charging voltages are reached, the charging resistor circuit is bypassed using a bypass switch/breaker. The Type and Rating of the charging resistor and associated bypass switch shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station and shall conform to the relevant Standard. C.8.1.5 STATCOM Valve Cooling system A closed-loop recirculating system shall be provided with full heat rejection capacity with redundancy for pumps, heat exchangers, and fans, appropriate to the STATCOM Station availability requirements. The cooling system should be able to maintain full capacity at maximum ambient temperature and maximum STATCOM reactive power output. The cooling system should be able to operate at the lowest ambient temperature and zero output specified. The Valve cooling system shall have black start capability and necessary Uninterruptible Power Supply UPS/ Uninterruptible Motor Drives UMD shall be provided separately for each STATCOM Unit. The valve cooling system shall be designed to meet the performance requirements described in this specification and as described below. a) Each STATCOM Unit shall have its own de-ionized water valve cooling system with redundant pumps. b) For cooling the STATCOM valves, a deionized re-circulating (closed loop) water system shall be used. c) Water to air heat exchanger shall be used for cooling of this de-ionized water. Water to water heat exchanger shall not be employed. d) System shall be designed such that no shut down of STATCOM be resorted to for making up the deionized water in the system. The make-up water should comply with the recommended pH and purity. e) Cooling water shall have a constant flow rate irrespective of loading. The flow rate shall be decided on the basis of extreme operating conditions. [Insert Name of the SPV] 155 ……2026Transmission Service Agreement f) The control system for the cooling system shall be redundant type including the provision of redundant control supply and main power supply. However, in place of the redundant control system for the cooling system, suitable alternate mode is also acceptable meeting the requirement of fulfilling cooling system operation even if failure of cooling control system. g) 2x100% pumps with one as standby shall be provided for the primary. In case a pump failure occur, the second pump shall automatically switch in without shutting down the STATCOM. An alarm shall be displayed at the control panel for the failure of the first pump and standby pump in operation. h) Each cooling system shall be provided with an independent/dedicated UMD supply however common battery for both UMD power supply may be accepted. An UMD system will provide an extended capability of the STATCOM Station to deliver reactive power without any interruption, adding a buffer against the system faults or during events such as delayed voltage recovery or Transient over Voltage (TOV). i) The secondary cooling system shall be a redundant type such that it shall be possible to take out 10% (minimum one number) of the cooler module (fan unit) of secondary cooling system without affecting the rated performance of STATCOM). j) Normally no make-up water shall be required however in case of expansion vessel level going low; the same shall be replenished automatically by means the of make-up water tank and make up water pump to be supplied with the system. k) TSP shall provide a water treatment plant of sufficient capacity. The purification (treatment) system shall be designed to maintain conductivity below 1 micro Siemens. A resistivity cell in the outgoing water from the deionizer should detect the depletion of ionized material. Filters and deionizers shall be designed to allow replacement during operation. Normal replacement shall not be required more than once every year. l) Filters and deionizer/deoxidizer material shall be designed to allow replacement within minutes without shutdown of the cooling unit. (Normal replacement should not be required more than once/year). m) Primary cooling system shall monitor its own operation and condition of cooling water. n) The protection system of the cooling cycle shall have minimum following alarms: i) Depleted deionizing cell ii) Low water resistivity iii) High water temperature [Insert Name of the SPV] 156 ……2026Transmission Service Agreement iv) Primary pump stopped v) Fan stopped vi) Primary pump or fan interlock circuits faulty vii) Primary cycle (Make-up water) tank level low viii) Failure of control supply. ix) UMD/UPS fault. o) Following shutdown alarms / TRIP shall be provided with cooling system protection. Excessive low water resistivity excessive high water temperature, complete loss of auxiliary supply to primary pumps, low flow, low pressure etc. p) The dissipative components of the converter are cooled with deionized water. q) The power losses are transferred to the external ambient by means of a deionized water /air heat exchanger. All the piping and other components shall be provided. Complete instrumentation set including following shall be mounted on board in order to check the status of the cooling system:  Conductivity gauge system.  Flow meter equipped with two set points (alarm and trip).  Pressure meter  Two thermometers for the inlet and two thermometers for the outlet (two set points for alarm and trip)  Thermostat r) The status of the cooling system shall be monitored by means of the control system. s) Replacement of certain cooling equipment (e.g. pumps, fans, cooler unit etc.), if defective, shall be possible while the cooling system still operates. C.8.1.6 Tests on STATCOM Unit Valve All applicable tests i.e. Operational Type Tests, Dielectric Type Tests and Test for valve insensitivity to electromagnetic disturbance and Production tests shall be done as per the latest edition of IEC 62927. C.8.2 STATCOM Station Control equipment and operator interface C.8.2.1 Control Equipment The control systems should achieve the functional objectives given in 6.2. The accuracy of voltage should be within ± 1% of the reference voltage. The accuracy of the gradient and linearity of the slope delivered by the STATCOM Station should be defined in relation to the current deviation from the [Insert Name of the SPV] 157 ……2026Transmission Service Agreement theoretical slope defined in 3.1. The maximum deviation should be less than ± 5% of the nominal current. The control system design shall be based on a single fail criterion i.e. failure of any one component in the system should not result into outage of the complete system. As a minimum, a dual (hot standby) digital programmable controller shall be supplied for each STATCOM unit/branch and STATCOM Station to control the STATCOM, MSRs and MSCs completely including the functions listed as mentioned below: a. The controller shall have diagnostic and self-checking features for both itself and for valves, gate firing and drive circuits, interface hardware, and software. This is required to reduce outage times and to facilitate fault finding. b. The Controller shall be reprogrammable. The Owner shall have at least the following possibility for changing the following reference and limit values via HMI: c. Closed loop Controllers: The STATCOM Station controller shall have the means to modify the reference set points. This refers to the functionality that will allow all the control parameters to be adjustable within selectable limits and is inclusive of, but not limited to following: o Voltage controller o Q controller (reactive power controller). o Supplementary VSC current controller. o Other supplementary control functions. d. Sequence Controllers: The sequence control and open-loop controllers shall include the control of all switchgears and associated control gear and external devices. e. The Controller shall have at least 10% excess I/O capacity to allow future program upgrades to satisfy the changing requirements of the power systems or future extensions to the STATCOM Stations. As a minimum, a control of up to 4 future HV shunt devices (reactors or capacitors) shall be included in the offer. f. All control signals available for remote control must also be available locally so as to ensure that a local operator can operate the STATCOM Station if the communications link between STATCOM Station and remote control centers is lost. g. A changeover switch shall be provided for control of the selection of local or remote control. [Insert Name of the SPV] 158 ……2026Transmission Service Agreement h. TSP shall provide the equipment necessary for the purpose of control, protection and interlocking of all equipment within the scope of supply. i. TSP shall be responsible for the design and coordination of control, protection and interlocking system and switching sequences within the STATCOM Station. All necessary interfacing required between AC switchyard equipment and STATCOM Station for the above purpose shall also be included in the scope of TSP. j. It is proposed to control STATCOM through a Supervisory Control and Monitoring System (SCADA). All the data shall be acquired through suitable means from the field and various components and control is executed through the redundant HMI. The local STATCOM Station Control system shall consist of a redundant STATCOM Station controller, redundant HMI workstation, Gateway, STATCOM Station Control System Engineering cum Disturbance Recorder (DR), PC which can also be used as standby HMI workstations in case of emergency with associated peripheral equipment such as color laser log Printers, Color laser jet fault record printer, GPS System, Inverter / UPS etc. all interconnected via redundant Ethernet based Station LAN Network. Each work-stations and PCs at STATCOM Station shall have at least 19” LED display. k. In addition to the above, HMI workstation (identical to HMI Workstation provided in the STATCOM Station control room) should also be provided in the control room of the main 400 kV substation. This HMI workstation should be powered from an independent UPS system adequate enough to provide power to the HMI workstation for a minimum two hours in case of auxiliary power failure. l. The control equipment shall satisfy the reliability and availability requirements specified in this specification m. All necessary measures shall be taken to ensure satisfactory operation in the presence of harmonic current and voltage, noise and radio interference signals. The equipment shall be designed to operate in the environmental conditions specified in the specification. n. There should be a provision for independent operation of MSC/MSR after delinking it with STATCOM controls when STATCOM is out of service due to any reason. o. The threshold values for switching the MSC/MSR on/off shall be configurable in all modes of operation. C.8.2.2 Operator Interface a) Each STATCOM Station shall have a SCADA consisting of an HMI which shall provide a Centralized (local) operator control of the STATCOM Station [Insert Name of the SPV] 159 ……2026Transmission Service Agreement functions. All human interface operations necessary for the control and monitoring of the STATCOM shall be provided at this point. b) Any abnormal condition requiring operator action or intervention or maintenance on any of the STATCOM Station subsystems shall be annunciated at the STATCOM Station control room and the Substation control room. c) The local HMI shall include the following diagrams as different screens in the display system: i. Complete STATCOM Units and STATCOM Station single line diagram including EHV and MV busses ii. AC Auxiliary supply and distribution iii. DC Auxiliary supply and distribution iv. STATCOM Valve cooling systems v. Interlocking system. d) These diagrams shall indicate status, alarms, voltages, currents, etc. The HMI shall provide complete diagnostics on alarm and trip indications as required and discussed in this specification, including SER information. e) A facility shall be provided whereby the local HMI features and functions shall be accessible from remote. A remote user shall be able to view screens and change STATCOM Station parameter settings. f) As the substation where STATCOM Station shall be installed, will be equipped with Sub-station Automation System (SAS) conforming to IEC 61850, it is required that STATCOM Station control and monitoring shall be integrated with SAS at the main Sub-station by the TSP. It is proposed to connect STATCOM Station’s SCADA with SAS through a Gateway and the database, configuration etc of the main substation SAS shall be upgraded to incorporate STATCOM Station events, alarms, Controls (both switchgear and control functions of STATCOM Station like the setting of parameters etc.) so that STATCOM Station can be effectively monitored and controlled from main substation SAS and shall be monitored from Load Dispatch Center (RLDC). C.8.3 STATCOM Station Protection System C.8.3.1 Protection system Design a) To ensure that faults are cleared within stability critical clearing time, to minimize damage to the plant, and to avoid voltage collapse, loss of load, or load limitations, TSP shall provide a high speed main protection [Insert Name of the SPV] 160 ……2026Transmission Service Agreement scheme. An independent (having a separate measurement system) back- up protection scheme shall be provided in the event of the main protection scheme failing or taken out for maintenance. b) The STATCOM Station shall be completely self-protecting (unit protection). STATCOM Station shall be protected from damage for all conditions of over-current, overvoltage, excessive reactive power loading, unbalance due to loss of capacitor elements, phase-to-phase and phase- to-ground faults, three phase faults, loss of cooling, semiconductor valve or control malfunction, faults (STATCOM, MV system) in individual primary connected components of the STATCOM, HV system faults, etc. The STATCOM Station shall withstand the maximum fault current for a period of the maximum fault clearing time as specified, considering second contingency cases due to the previously mentioned conditions. c) All protection equipment and systems should be properly co-ordinated to prevent incorrect operations of the protection equipment or systems during normal STATCOM Station operation, including anticipated abnormal conditions on the transmission system, as specified. Fail-safe principles should be applied throughout. C.8.3.2 The basic principle and order of precedence for the control and protection shall be, to take care of the following: • Correctly identify a fault, problem or error condition, • Only if necessary, isolate the minimum number of components, subsystems whenever possible, • Utilize degraded modes to the maximum extent possible either directly (no interruption of the STATCOM Station operation) or indirectly (by tripping the STATCOM Station momentarily in order to isolate the branch and re-energization of the STATCOM Station). • Trip STATCOM Station and Block. a) Failure of the STATCOM Station Interface (SCADA interface) shall not result in a Protection trip of the STATCOM Station. A fail-safe philosophy shall be implemented to allow the STATCOM Station to operate safely and independently from the STATCOM Station Interface (SCADA interface). b) Protection equipment shall be designed and applied to provide maximum discrimination between faulty and healthy circuits. c) The Protection shall be sufficiently sensitive to cater to the full range from maximum to minimum fault level conditions. The Protection shall also be suitable for a system fault level equal to the maximum [Insert Name of the SPV] 161 ……2026Transmission Service Agreement short circuit capacity of the substation. All current transformer designs shall be based on these fault levels. d) All required protective, control devices, etc including auxiliary instrument transformers and panels, relays, cabling, wiring, indication, and all other associated plant and material necessary for the effective operation of the protection systems shall be supplied and installed by TSP. e) The protective relays shall be microprocessor based. Relays shall have approved characteristics and be mounted in dust and moisture- proof cases. The protective relays shall be provided with visual indications for starting, tripping and failure of the protective function. The LEDs shall be reset without opening the covers. The protection relays shall also be equipped with HMI facilities suitable for manual parameter settings and viewing of the settings. Relays with provision for manual operation from outside the case, other than for resetting, are not acceptable. Relay settings shall be visible and readable without having to remove the relay cover. Relays shall be of approved construction and shall be arranged so that adjustments, testing and replacement can be effected with the minimum of time and labor. Auxiliary Relays of the hand reset type, if provided shall be capable of being reset without opening the case. Electrically reset tripping relays shall be provided as necessitated by the system of control, such as for those circuits subject to remote supervisory control. f) Relay contacts shall be suitable for making and breaking the maximum currents which, they may be required to control in normal service but where contacts of the protective relays are unable to deal directly with the tripping currents, approved Auxiliary tripping relays shall be provided. In such cases, the number of auxiliary tripping relays operating in tandem shall be kept to a minimum in order to achieve fast and reliable fault clearance times. Separate contacts shall be provided for alarm and tripping functions. Relay contacts shall make firmly without bounce and the whole of the relay mechanisms shall be as far as possible unaffected by vibration or external magnetic fields g) Steps shall be taken to protect the circuitry from externally impressed transient voltages which could reach the circuitry via connections to instrument transformers or the station battery. The routing of cables should be such as to limit interference to a minimum. Any auxiliary supplies necessary to power solid-state circuits shall be derived from the main station battery and not from batteries internal to the protection. [Insert Name of the SPV] 162 ……2026Transmission Service Agreement h) Relay communication The Relays shall also have a communication port provided on the front of the relay for configuration and parameter settings as well as downloading of data. A direct port suitable for remote communication shall also be provided at the back of the Relay. This port shall conform to IEC - 61850. i) Tripping schemes  Tripping of MV circuit breakers shall be done by means of two- separated trip signals.  Duplicate high security tripping circuits for MV Circuit Breaker shall comprise two independent high speed (less than 10 ms) high burden (greater than 150 W) tripping relays for each circuit, each with its own independent DC supply. The trip circuits for all circuit breakers need to be equipped with a “lockout” function and it shall be possible for this to be reset manually and remotely by the operator. j) The protection for the power system is based on a normal switching state and an occurrence of a single fault. This means that faults resulting from maintenance as well as the simultaneous occurrence of two or more faults are not taken into account. k) The input circuits of the digital protections shall be monitored by means of a plausibility check. If any incorrect information is found, the protection function shall be blocked by the protection system. All protection relays shall have facilities for monitoring trip circuits. Detection of an interruption in the case of a switched on circuit breaker shall be signaled. l) Test facilities  It shall be possible to test the protective device during operation without causing trips. Links shall be provided for the isolation of individual protection trip circuits and the common protection trip circuit to each circuit breaker trip coil.  Separate test facilities shall be provided for each current and voltage transformer secondary circuit so as to give access for testing of protection relays and associated circuits. The Test facility to be supplied shall have two selectable positions, a Service and a Test position. In the service Position, the test switch connects CTs and VTs signals to the Relays and trip commands to the circuit breaker trip coils. In the Test Position, the test switch applies a short-circuit to the Current Transformer (CT) secondary windings and open circuits the VT secondary cores and allow injection of secondary current and voltage into the relay. At the same time, the [Insert Name of the SPV] 163 ……2026Transmission Service Agreement Trip commands to the Circuit Breaker Trip Coils are isolated. The test switch supplied shall be to the Approval of the Owner. m) The protection of the electrical system shall be designed and installed in such a way that the failed equipment is disconnected selectively and automatically. All equipment have to remain operative during transient phenomena, which may arise during switching or other disturbances to the system. n) Auxiliary DC Supplies  The protection concept has to be designed in a way so that back- up protection is provided at all times. All protection relays shall be configured in a way that failure of one Auxiliary DC system will not affect the relay. If all DC supplies to the controllers are lost, the STATCOM Station breaker must be tripped via the protection panel. o) Electromagnetic Compatibility  Electronic Relays and other electronic devices and the ancillary circuits connected to them, such as power supplies, current and voltage transformer secondaries, status or tripping or alarm circuits shall be designed to ensure that they are compatible for use in the hostile electrical environment found in an MV or HV substation.  Adequate steps by means of suitable design, shall be taken to prevent Electromagnetic Interference (EMI), (generated by sources such as circuit breakers, disconnectors, lightning, radio or radar emissions, switching contactors in DC circuits etc) or Electrostatic Discharges (ESD) from affecting relay performance or causing damage to components.  All relays offered shall therefore have been type-tested to meet the current requirements of IEC Standards with respect to High Frequency disturbance, Fast Transients, Electrostatic Discharge, Radio Frequency Interference testing etc. p) List of Protection functions for STATCOM Station Coupling Transformer Protection: i) Biased Differential protection (87T) ii) REF protection (64T) iii) Overcurrent protection (50, 51) iv) Ground Overcurrent (51N) v) Over flux protection (HV and MV) vi) Transformer mechanical trips STATCOM MV Bus Protection: [Insert Name of the SPV] 164 ……2026Transmission Service Agreement i) Bus Differential protection (87) ii) Ground over current protection (51N), used with a neutral Grounding Transformer iii) Under / Over Voltage (59 Ph-Ph) protection iv) Over voltage (Open Delta) protection STATCOM Branch Protection: i) Differential protection (87) ii) Overload protection (49) iii) Overcurrent protection inside delta (50, 51) iv) Negative phase sequence protection (46) v) STATCOM branch overcurrent protection (50, 51, 50N, 51N) MSR Branch Protection: i) Differential protection (87) ii) Ground over current protection (51N) iii) Reactor branch unbalance protection (Negative Phase Sequence) iv) Thermal Overload protection MSC Branch Protection: i) Ground over current protection (51N) ii) Capacitor Overvoltage (Using current signal) protection. iii) Capacitor unbalance protection (60C) iv) Over current protection (50, 51)  The protection functions listed above are the minimum set of function to be provided, any additional protection required to fulfill the requirement of the protection system shall also be provided.  Further protection functions of individual branch (STATCOM, MSC, MSR) shall trip the respective branch MV Circuit Breaker (CB).  All CBs shall be provided with individual Breaker Failure protection relays. Breaker Failure relay shall have the logic based on the current signal or Circuit Breaker close open status.  Any fault on MV bus will trip the 400 kV breaker. However, any branch fault shall be cleared by the respective MV branch Circuit Breaker.  Protection System for the STATCOM valve portion of the STATCOM station shall be provided in the redundant controllers to isolate the STACOM valve during internal overload/overvoltage, ground fault etc. C.8.4 STATCOM Station Fault Recording System [Insert Name of the SPV] 165 ……2026Transmission Service Agreement An integrated Transient Fault Recording (TFR) System shall be supplied, installed and commissioned. This shall include trigger level settings for analog signal, etc subject to review and comment. Disturbance and event recording facilities are required for local monitoring of the STATCOM following a disturbance on the power system or the STATCOM System. The TFR shall be GPS/NavIC synchronized. The following inputs are required:  All analog signals (output signals) including 3-ph and sequence values of voltage, current.  All digital signals (control outputs, status indications, commands, alarms, and trip indications). Internal STATCOM Station control signals/variables to be selectable.  The accuracy of the TFR for event inputs shall be at least 100 μs (sampling rate of minimum 10 kHz).  The TFR shall have provision for remote access and retrieval of recorded information onto a PC. For this purpose, a communication link to the substation LAN shall be implemented.  The remote software application for data retrieval shall be included.  There shall be multiple channels to view 3-ph and sequence values of voltage, current.  TFR file shall be viewable in any open source software. C.8.5 Mechanically Switched Reactor (MSR) MSR is a fixed source of inductive reactive power connected in shunt to the MV bus of STATCOM Station and switched by means of a circuit breaker (with a control switching device) based on the command from the STATCOM Station control system. The rated capability of MSRs shall be at 400 kV (Referred to as “Point of Common Coupling” or PCC) and in the steady state frequency range of 48.5 Hz-50.5 Hz. However, the MSR Components shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The individual components of MSR shall be able to withstand the onerous conditions imposed by system overvoltage and harmonics. The MSR consists of 3-ph Air Core Reactor, 3-ph MV Circuit breaker (SF6/Vacuum type), associated current transformer, 3-ph Disconnector and associated safety grounding switch. The MSR area shall be fenced and a castle key interlock with safety grounding switch shall be provided for human safety. Specifications for individual components like Air core reactors etc are provided in the subsequent clause. [Insert Name of the SPV] 166 ……2026Transmission Service Agreement C.8.6 Mechanically switched capacitor (MSC) MSC is a switched 3-phase capacitor bank connected in shunt to the MV bus of STATCOM station and switched automatically by means of a circuit breaker (with control switching device) based on the command from STATCOM Station control system. The rated capability of MSCs shall be at 400 kV (Referred to as “Point of Common Coupling” or PCC) and in the steady state frequency range of 48.5 Hz-50.5 Hz. However, TSP will ensure the corresponding values at PCC (400 kV) for possible operating condition measured at PCC. The MSC Components shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The individual components of MSC shall be able to withstand the onerous conditions imposed by system overvoltages and harmonics. The MSC consists of 3-ph AC power capacitor bank, a current limiting air core reactor as required, 3-ph MV Circuit breaker (SF6/Vacuum type), associated current transformer, 3-ph Disconnector and associated safety grounding switch. The MSC area shall be fenced and a castle key interlock with safety grounding switch shall be provided for human safety. Specifications for individual components like Capacitors, Air core reactors etc are provided in the subsequent clauses. C.8.7 Air Core Reactors a) Reactors shall be air core, dry type, be suitable for outdoor installation and there shall be no tapping on the reactors. The insulation level shall be adequate and TSP has to ensure proper insulation coordination. b) The insulation of the reactor shall be class F and hot spot temperature rise shall not exceed 105 °C above ambient temperature. Winding temperature rise shall not exceed 80 °C above ambient temperature. c) The reactor shall be designed to withstand thermal dynamic shocks and mechanical shocks while in service and during erection. d) The reactor shall fully conform to the relevant IEC standard. e) The reactor shall be designed to withstand overloading due to over voltage as specified and shall also be subjected to excitation by harmonics; the reactor must be able to withstand such events without deterioration in normal life. f) The reactors shall be subjected to type and routine tests in accordance with the latest issue of IEC-60076 as appropriate to the type of reactor provided. [Insert Name of the SPV] 167 ……2026Transmission Service Agreement g) Tests on Reactors: The reactors shall be subjected to type and routine tests in accordance with the latest issue of IEC-60076 as appropriate to the type of reactor provided. C.8.8 AC POWER CAPACITORS i) General a) The capacitor banks shall comprise capacitor units, discharge devices, protection equipment, series reactor as required, earthing switches, suitably connected in series and parallel, mounted at ground level with protected fencing all around. The number, arrangement and connection of capacitor banks shall be designed to suit the requirement of the compensator as a whole. If convenient, the capacitor banks may be used in conjunction with reactors. In this event, the rating of the capacitor shall be adequate to cope up with the harmonic loading. The frequency variations shall also be considered. To limit the peak inrush current for switching in the capacitors, current limiting reactors with parallel connected damping resistors, if required shall be connected in series with shunt capacitor banks. b) The capacitors shall be provided with internal-type fuses. Alternatively, the fuseless capacitor is also acceptable. c) Fuses shall not melt nor shall deteriorate when subjected to the inrush current during the life of the capacitor bank. d) With the capacitor charged to a peak voltage, the fuses associated with the healthy elements shall not melt when carrying the discharge current resulting from a breakdown of an element or from an external short circuit. e) Fuses shall be capable of disconnecting a faulty element over a range of voltage across the unit terminals from 0.9 Un to 2.0 Un. In addition, if all the elements in the same row of an internally fused capacitor were to fail as a result of a cascading action, the last fuse element to melt shall be capable of successful disconnection with a voltage of not less than 1.5 times. f) After fuse operation the fuse assembly shall be able to withstand continuously at least 1.5 times the rated unit voltage Un across the gap for 10 Seconds. g) Fuses shall preferably be of the current limiting type but fuse system shall in any event be designed to ensure that energy released into a faulty capacitor unit is less than the valve that will cause rupture or bursting of the container. h) The capacitor units shall be the outdoor type. The container of the capacitor shall be of stainless steel. i) Each capacitor unit shall be readily accessible and replaceable without disturbing any other unit. The supporting frames shall be designed to provide adequate ventilation to the units. [Insert Name of the SPV] 168 ……2026Transmission Service Agreement j) The dielectric fluid used in the capacitor unit shall be environmentally safe and bio-degradable, non-toxic. Polychlorinated Biphenyle (PCB) type dielectric or any of its derivatives shall not be acceptable. ii) Construction and Design Requirement a) The capacitors shall conform to IEC-60871. The capacitors shall be provided with internally mounted discharge resisters with characteristics in accordance with IEC-60871. b) The current limiting reactors (as required) shall be dry type and connected in series with the capacitor bank. Suitable lifting lugs shall be provided. c) The capacitor enclosure shall have sufficient strength to withstand without damage or loss of life, mechanical load, both in operation and during erection. The loads shall include electromagnetic forces including those during faults external or internal to the capacitor bank, wind loading, forces due to expansion and contraction caused by ambient temperature and load variation, and seismic effects all as specified. d) The capacitor units shall be interchangeable in order to reduce the spare requirements and simplify maintenance procedures. e) The capacitor stack shall be vibration free. The stack shall have a fixed potential, which is connected to one electrical point in the bank. The stack shall be of galvanized structural steel. f) The capacitor racks shall be supplied complete with all capacitor units, insulators, and connections and shall be equipped with lifting lugs/eyes to facilitate assembly into the stacks. The racks shall be constructed of galvanized structural steel. No drilling of galvanized steel shall be allowed. Each rack shall be labeled with the weight of the fully equipped racks, the phase, and the bank of which it forms a part. The maximum and minimum capacitor unit capacitance which may be substituted into the racks as spares shall be suitably identified. Suitable warning labels shall be affixed. g) The capacitor shall be specially designed to be suitable for intermittent duty. h) The capacitors should comply with the overload capacity as per NEMA Standard. i) The capacitor elements shall be vacuum dried inside the case prior to impregnation with dielectric fluid. After impregnation, the capacitor unit shall be sealed immediately upon removal of the impregnated reservoir. j) The discharge resister shall discharge the unit from peak operating voltage to less than 75 Volts within 10 minutes. [Insert Name of the SPV] 169 ……2026Transmission Service Agreement k) The capacitor case shall be made from type 409 stainless steel or equivalent stainless steel with all joints welded and tested for leaks. l) All racks and bus insulators as well as the insulators used to insulate each stack of capacitor from ground level shall be pincap or post type. The minimum voltage rating shall be 15 kV and low frequency wet withstand voltage of all insulators used to insulate within or between the capacitor rack of a stack shall not be less than three times the actual voltage stress across the insulators. The insulator shall be outdoor type manufactured from wet porcelain. The insulators shall be bolted to the top members of the frame to support electric-grade aluminum buses. m) The size and groupings of the individual capacitor units shall be such that a single blown fuse will not cause the voltage across the parallel group to rise by more than 10%. n) The redundancy to be provided, shall be as per the requirement specified regarding reliability and availability in the clause mentioned elsewhere. iii) Capacitor Unit Failure Detection The stages of capacitor units or element failure detection shall be provided as below: a) A three-step unbalanced current protection shall be provided in each capacitor bank to initially generate an alarm when the unbalance limit is reached and finally to trip the bank in case of the limit is exceeded. b) The first stage shall generate an alarm and the capacitor unit shall continue in service. It may be assumed that the bank shall be disconnected for maintenance within 2 weeks. c) The second stage shall generate a separate alarm and a delayed trip signal which will disconnect the bank after two hours. d) The third stage shall cause immediate disconnection of the Capacitor Bank. iv) Tests on Capacitors All the tests on capacitor units shall be in accordance with the latest issue of IEC 60871. C.8.9 Coupling Transformer [Insert Name of the SPV] 170 ……2026Transmission Service Agreement The TSP shall provide single phase coupling transformers to operate as 3- phase bank with one unit as a common spare with necessary auxiliary arrangements for stepping down the voltage from 400 kV system to a suitable medium voltage value as required for replacing any one of the faulty phase units without physically shifting the transformer. The Medium Voltage side of the coupling transformer to couple with the STATCOM shall not be less than 20 kV to ensure optimum power transformation. The Coupling Transformer shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. The transformer should be designed and rated to carry complete capacitive and inductive reactive loading as specified for STATCOM Station including that of mechanically switched capacitors (MSC) and Reactors (MSR) etc., as well as harmonic currents associated with the most onerous operating conditions of STATCOM Station, without loss of life. The coupling transformer shall be designed in accordance with the most up- to-date experience in STATCOM application and shall incorporate the latest improvements of design currently employed in the industry. The Comprehensive design review of the Coupling Transformer of STATCOM Station shall be carried out by the TSP. C.8.9.1 General Requirements The coupling transformer shall be designed electrically and mechanically for operating conditions peculiar to STATCOM Station operation, which shall include, but not be limited to the following: a) Electrical insulation problems resulting from the transformer being subjected to voltages of distorted sinusoidal wave shape because of saturation, harmonics, trapped charges in capacitors etc. b) The cumulative effect of electro-dynamic forces produced during valve commutation or other short circuit conditions imposed by valve design limitation and valve group operation. c) Harmonic currents due to STATCOM operation, with reference to additional stray losses resulting from these harmonic currents. d) No generation of uncharacteristic harmonics by the transformers. e) Stresses due to normal control operation and other onerous operations such as blocking and de-blocking. f) Stress due to the fast response requirement of STATCOM for loading from 100% inductive to 100% capacitive and vice-versa. g) Overvoltage stresses for which STATCOM shall be designed as per specification would apply to the transformer also. [Insert Name of the SPV] 171 ……2026Transmission Service Agreement h) All other stresses for which STATCOM Station shall be designed as per specification would apply to the transformer also. i) The transformer and all its accessories like Bushings, CTs etc shall be designed to withstand without damage, the thermal and mechanical effects of any external short circuit to earth and of a short circuit across the terminals of any winding for a period of 3 seconds. The short circuit level of the 400 kV system to which the transformer shall be connected, will be as per the maximum short circuit level of the main substation. Short Circuit level of the Coupling Transformer shall be as per the Short Circuit level of the respective Substation. Short circuit level for HV bushing shall be 63 kA for 1 Sec. j) The transformer shall be capable of being loaded in accordance with IEC 60076 or the overload conditions as specified whichever is the worst. There shall be no limitation imposed by bushings during its terminal fault. k) The transformer shall be capable of withstanding the mechanical stresses caused by symmetrical or asymmetrical faults on any winding. l) The transformer should be designed to carry a certain level of direct current consistent with the STATCOM design. To ensure minimum harmonics generation, the saturation flux density of the transformer should be higher than the maximum flux density reached over the full steady state (continuous operating) range; this margin shall be at least 10%. This maximum flux density (over the full steady-state range) is obtained at the highest secondary voltage during any reactive power generation, highest reference voltage, minimum slope, and minimum continuous frequency. The flux density at the highest secondary voltage shall lie in the linear portion of the BH curve of the core. Any harmonic generated by the transformer should be considered for the design of the STATCOM. m) All protection class Current Transformers in the coupling transformer shall be of PX/PS type. Other details of these Current Transformers shall be as per protection/metering requirements and shall be decided during detailed engineering. However, the parameters of the Winding Temperature Indicator (WTI) of Current Transformer for each winding shall be as per the Coupling Transformer manufacturer. n) Transformers shall be capable of operating under natural cooled conditions up to the specified load. The forced cooling equipment shall come into operation by pre-set contacts of winding temperature indicator and the transformer shall operate as a forced cooling unit initially as Oil Natural Air Forced (ONAF) up to a specified load and then as Oil Forced Air Forced (OFAF). Cooling shall be so designed that during total failure of power supply to cooling fans and oil pumps, the transformer shall be able to operate at full load for at least ten (10) minutes without the calculated winding hot spot temperature exceeding 140 ° (degree) Celsius. Transformers fitted with two [Insert Name of the SPV] 172 ……2026Transmission Service Agreement coolers, each capable of dissipating 50 percent of the heat due to losses at the continuous maximum rating, shall be capable of operating for 20 minutes in the event of failure of the oil circulating pump or blowers associated with one cooler without the calculated winding hot spot temperature exceeding 140 ° degree Celsius at continuous maximum rating. o) The transformer shall be free from any electrostatic charging tendency (ECT) under all operating conditions when all oil circulation systems are in operation. In general, the oil flow speed shall not exceed 1.0 m/sec within winding in the oil flow system of the transformers. The manufacturer shall ensure that there is no electrostatic charging tendency in the design. The Technical Parameters of the Transformer shall be as below Sl. Description Unit Technical Parameters No. 1.1 Rated Capacity HV MVA To meet the performance requirement and ratings of MV MVA STATCOM. The transformer shall be suitable for 100% reactive loading 1.2 Voltage ratio (Line to Line) 400 / XX (*) 1.3 Single / Three Phase Single phase Design 1.4 Applicable Standard IEC 60076 1.5 Rated Frequency Hz 50 [Insert Name of the SPV] 173 ……2026Transmission Service Agreement Sl. Description Unit Technical Parameters No. 1.6 Cooling and Percentage ONAN/ONAF/(OFAF or Rating at different coolings ODAF): 60% / 80%/100% OR ONAN/ONAF1/ONAF2: 60% /80%/100% OR OFAF (with 5 x 25% unit cooler if required) 1.7 Impedance at 75 oC (in percentage) HV–MV To suit the design requirements. 1.8 Tolerance on Impedance % As per IEC (HV-MV) 1.9 Service Outdoor 1.10 Duty Continuous Reactive loading 1.11 Overload Capacity IEC-60076-7 1.12 Temperature rise over 50 oC ambient Temp i) Top oil measured by 0C 50 thermometer ii) Average winding measured 0C 55 by resistance Method 1.13 Windings i) System Fault level [Insert Name of the SPV] 174 ……2026Transmission Service Agreement Sl. Description Unit Technical Parameters No. HV kA 63 MV kA To suit the design requirements. ii) Lightning Impulse withstand Voltage HV kVp 1425 MV kVp * Neutral kVp 170 iii) Switching Impulse withstand Voltage HV kVp 1175 iv) One Minute Power Frequency withstand Voltage HV kVrms 570 MV kVrms * Neutral kVrms 70 v) Neutral Grounding Solidly grounded vi) Insulation HV Graded MV Uniform vii) Tan delta of winding % < 0.5 [Insert Name of the SPV] 175 ……2026Transmission Service Agreement Sl. Description Unit Technical Parameters No. 1.14 Vector Group (3 – ph) YNd* (unless specified differently elsewhere) 1.15 Tap Changer Not Applicable 1.16 Bushing i) Rated voltage HV kV 420 MV kV * Neutral kV 36 ii) Rated current (Min.) HV A * MV A * Neutral A * iii) Lightning Impulse withstand Voltage HV kVp 1550 MV kVp * Neutral kVp 170 iv) Switching Impulse withstand Voltage HV kVp 1175 [Insert Name of the SPV] 176 ……2026Transmission Service Agreement Sl. Description Unit Technical Parameters No. v) One Minute Power Frequency withstand Voltage HV kVrms 695 MV kVrms * Neutral kVrms 77 vi) Minimum total creepage distances HV mm/kV 31 MV mm/kV 31 Neutral mm/kV 31 vii) Tan delta of bushings HV % Refer Note 2 MV % Refer Note 2 viii) Max Partial discharge level at Um HV pC 10 MV pC 10 Neutral - 1.17 Max Partial discharge level pC 100 at 1.58 * Ur /√3 1.18 Max Noise level at rated dB 80 voltage and at principal tap [Insert Name of the SPV] 177 ……2026Transmission Service Agreement Sl. Description Unit Technical Parameters No. at no load and all cooling Active 1.19 Maximum Permissible Losses of Transformers i) Max. No Load Loss at rated kW To suit the design voltage and Frequency requirements. ii) Max. Load Loss at kW To suit the design maximum continuous requirements. current and at 75O C iii) Max. Auxiliary Loss at rated kW To suit the design voltage and Frequency requirements. Notes: 1. No external or internal Transformers / Reactors are to be used to achieve the specified HV/MV impedances. 2. The criteria for Transformer losses shall be “Copper Loss (Load Loss) > Iron Loss (No Load Loss) > Cooler Loss (Auxiliary Loss)”. 3. (*) marked parameters shall be decided based on STATCOM manufacturer’s requirement. C.8.10 STATCOM Station MV Switchgear The MV Switchgear shall be designed with the aim to achieve operation according to the overall performance requirements of the STATCOM Station. C.8.10.1 MV Circuit Breaker The MV Circuit Breaker shall comply with the relevant IEC standard and all other relevant Standards, and as specified in this specification. They shall satisfy the General Technical Requirements and shall be designed to operate in the environmental conditions specified in this specification. [Insert Name of the SPV] 178 ……2026Transmission Service Agreement The Circuit Breaker offered should be of SF6 type/Vacuum type only and of class C2, M2 as per IEC i) The circuit breaker shall be complete with terminal connectors, operating mechanism, control cabinets, piping, interpole cable, cable accessories like glands, terminal blocks, marking ferrules, lugs, pressure gauges, density monitors (with graduated scale), galvanised support structure for CB and control cabinets, their foundation bolts and all other circuit breaker accessories required for carrying out all the functions the CB is required to perform. ii) All necessary parts to provide a complete and operable circuit breaker installation such as main equipment, terminals, control parts, connectors and other devices whether specifically called for herein or not shall be provided. iii) The support structure of the circuit breaker shall be hot dip galvanized. Exposed hardware items shall be hot dip galvanized or Electro-galvanized. iv) MV Circuit Breaker shall be equipped with controlled switching with consequent optimization of switching behavior, when used in:  Switching of Capacitor Bank  Switching of shunt Reactor Bank v) Reactor Switching Duty test shall be conducted on MV Circuit Breaker in line with latest edition of IEC 62271-110. vi) Type Tested for Back-to-Back Capacitor Bank Switching as per latest edition of IEC 62271-100. vii) Routine tests as per IEC: 62271-100 shall be performed on all circuit breakers. [Insert Name of the SPV] 179 ……2026Transmission Service Agreement viii) The medium voltage circuit breakers in any of the branches shall be designed to switch off metallic three phase short circuits only limited by the transformer impedance of the STATCOM System (Coupling transformer) with the initial short circuit current and DC component according to IEC 60909-0. Thereby the worst case time constant where the maximum short circuit peak and DC component occur shall be considered. The network shall be considered to deliver the maximum short circuit power of the substation. C.8.10.2 MV Isolator and Earth Switch The isolators and earth switches shall comply with the IEC and all other relevant Standards, and as specified in this specification. They shall satisfy the General Technical Requirements and shall be designed to operate in the environmental conditions specified in this specification. i) The isolators and accessories shall conform in general to IEC-62271 series as per relevance (or IS:9921) except to the extent explicitly modified in specification. ii) Earth switches shall be provided on isolators wherever called for. iii) Switches shall be motor operated with local and remote operation features and local manual operation features. Remote operation of Earth Switch is not required. iv) Disconnections and earth switches shall electrically and mechanically be interlocked. Castle Key interlocking facilities shall be provided to mechanically interlock the earth switch and Isolator to the doors of valve rooms. C.8.10.3 Instrument Transformers for STATCOM Station The instrument transformers shall comply with the relevant IEC Standards. They shall satisfy the general Technical Requirement specified in the specification and shall be designed to operate in the environmental conditions specified in this Specification. The instrument transformers provided for control, metering and protective relaying functions shall have voltage and current ratings, accuracy ratings and burden capabilities adequate to provide their designated functions within the overall accuracy requirement of the systems. Voltage Transformers Voltage transformers shall comply with the relevant IEC standards IEC 61869 (Part-1, Part-3 and Part-5). Current Transformers [Insert Name of the SPV] 180 ……2026Transmission Service Agreement Current transformers shall comply with IEC 61869 (Part-1 and Part-2). Type tests and routine tests as per relevant IEC. C.8.10.4 Surge Arrester TSP shall install the surge arresters necessary for the protection of the equipment associated with the STATCOM Station in accordance with the requirements as per the insulation coordination study. The surge arresters shall give consistent protection to their associated equipment against overvoltage produced by lightning or switching surges, internal or external station faults, and other system disturbances. The surge arresters shall be rated such that they are able to discharge a specified maximum energy due to the application of lightning, switching surges, temporary over voltages and faults as determined by insulation coordination studies, without coming into the temperature region where thermal runaway could result upon subsequent application of maximum transient and steady state voltage conditions. The arrester housing shall be porcelain/composite type. The end fittings shall be made of non-magnetic and corrosion proof material. Internal components shall be designed to eliminate internal corona and also to ensure minimal capacitive coupling with any conducting layer of pollutant on the outside of the porcelain housing. Particular attention shall be given to the high discharge currents which some of the arresters may experience in service due to discharge of stored energy of the AC filter and reactive compensating equipment, tripping of STATCOM etc. C.8.11 STATCOM Station Auxiliary Power Supply The auxiliary supply of STATCOM Station shall conform with the system requirements relating to reliability, availability, and redundancy, performing continuously to help ensure that the complete STATCOM Station operates as per the requirements. STATCOM station Auxiliary supply including all necessary switchgear (viz. AC/DC, lighting boards etc.) shall be completely separate from the main 765/400/220 kV substation auxiliary supply, all loads of STATCOM station shall be fed from this supply. The auxiliary supply provides power to the controllers, cooling system, station supplies, and various other essential and non-essential loads. With the exception of the cooling system, all other essential loads are also connected to the DC system of the STATCOM Station which is also to be provided separately from the DC system of the main 765/400/220 kV substation. [Insert Name of the SPV] 181 ……2026Transmission Service Agreement The auxiliary supply system shall be able to provide a stable supply for the STATCOM Station during system faults such as single-phase faults, phase- to-phase faults, and three-phase faults and LVRT (Low Voltage Ride Through) to allow continuous operation of the STATCOM Station during these transient events. Auxiliary Supply System of each STATCOM Station shall be fed from two independent sources as per CEA (Technical Standards for Connectivity to the Grid) Regulations, 2007. Additionally, there shall be one emergency incomer from the DG set. Wherever the Voltage variation on the incomer is very high, a solid state AVR (Automatic Voltage Regulator) shall be provided to control the auxiliary supply voltage. All MV incomers shall be provided with suitable CB, disconnector, instrument Transformer etc along with necessary protection system. C.8.12 Fire Protection System for STATCOM Station: Necessary fire protection for STATCOM units, Coupling Transformer, MSC, MCR and Harmonic filter (if any) shall be required. The main features of these protections are as under. Fire Detection and Alarm System: Suitable fire detection system using smoke detectors and/or heat detectors shall be provided in STATCOM Station for all room and areas. These smoke fire detection systems shall be connected to a separate Fire annunciation system clearly identifying the zone. Hydrant System: The hydrant system shall be extended from fire-fighting system of the substation in the yard. Suitable number of hydrants shall be provided for protection of STATCOM Station equipment in the yard namely Coupling Transformer, MSCs, MSRs and Harmonic Filter (if required) etc as applicable for the station. Further suitable number of hydrants shall also be provided for STATCOM Station building HVW System: [Insert Name of the SPV] 182 ……2026Transmission Service Agreement HVW (High Velocity Water) Spray system shall be provided for coupling transformer. The tapping for HVW system shall be done from nearby transformer/Reactor or any other suitable point of the main substation fire- fighting line. Fire protection system shall be provided in accordance with the Central Electricity Authority (Measures relating to Safety and Electric Supply) Regulations, 2023. C.8.13 Air-conditioning and ventilation system for STATCOM station The STATCOM Station shall be provided with Air conditioning system as per requirement. 1) AC System (Except Valve Hall): Air condition system shall be provided for the following rooms in the STATCOM Building: a. Control and Relay room b. Battery room c. Conference Room d. Store cum workshop e. Cooling system room f. Lobby Capacity and quantity of the AC units shall be decided based on heat load calculation and redundancy requirement. 2) Air-Conditioning System for Valve hall: Air-Conditioning shall be provided for each Valve room for maintaining the following inside conditions round the year: DBT - 35 oC (Maximum) Relative Humidity (RH) - 60% (Maximum) The system shall be designed for an outside ambient temperature of 50 oC. Based on the above system design and parameters for valve room the AC system shall comprise “AHU and Air-cooled DX Condensing units” with one Main and one Standby unit for each room. The system shall be designed for 24 Hours, 365 Days of the year operation to maintain the inside temperatures of the Valve Hall for proper operation of the critical equipment. The air-cooled condensing unit shall be designed for continuous duty. C.9 Engineering studies [Insert Name of the SPV] 183 ……2026Transmission Service Agreement The TSP shall carry out studies as brought out in this section with a model of the STATCOM in PSSE and PSCAD and documentation of the same shall be preserved and to be submitted to CEA/CTU, as per their requirement. The objective of these studies is to verify the steady state requirement of reactive power under normal and contingent operating conditions for peak and light loads conditions in the network. The studies shall have to be carried out for - Peak Load - Light Load - Contingency Conditions The load flow and dynamic file available with CTU shall be provided to the TSP in PSSE version 34 format. If data is not available typical data shall be assumed by TSP. The studies should demonstrate that the STATCOM system meets all system and equipment specified performance criteria as per the specification. Engineering studies should include, but not be limited to, the studies described in subsequent subsections. C.9.1 System dynamic performance studies Dynamic performance studies should verify that the STATCOM system controls the system’s dynamic performance during system disturbances. Dynamic performance studies include the following: a. Studies verifying that the STATCOM provides adequate dynamic control to meet the system and STATCOM system performance criteria for the system conditions. b. Study of response time and of the STATCOM system’s behavior and contribution to the system’s recovery from faults. c. Studies to verify the operation of any supplementary controls designed to damp power oscillations following system disturbances. d. Studies to evaluate the interaction of the STATCOM controls with the other nearby control systems, including high-voltage direct current (HVDC) controls, generator controls, and controls of other flexible AC transmission systems (FACTS) devices In addition to the above, relevant studies shall include the cases stated as mentioned in Annexure-I C.9.2 Harmonic performance [Insert Name of the SPV] 184 ……2026Transmission Service Agreement The studies should evaluate resultant maximum harmonic levels at the STATCOM system point of common coupling (PCC), and determine maximum stresses on all STATCOM system components. The study report should include the following: a. Evaluation of specified system and operating conditions (refer to Clause 5) under all possible STATCOM operating conditions. b. Evaluation within maximum ranges of STATCOM system component tolerances (worst performance values may not occur at detuning extremes). c. Evaluation with maximum system voltage unbalance (refers to item 8 and item 9 in Table 3 of Clause 5). d. Evaluation of the worst case resonance condition between STATCOM system and overall system. e. Evaluation of possible resonant over voltages. f. Transformer saturation induced harmonics for component rating calculation only. g. Evaluation of impact considering single phase auto reclose deadtime. C.9.3 Electromagnetic transients, control performance, and overvoltage studies Transient overvoltage studies should be performed with the actual control modeled to verify that the STATCOM system equipment is adequately protected against over voltages and over currents (including excessive valve recovery voltages) from power system transients resulting from switching, fault clearing events, and credible STATCOM system maloperations. Evaluation shall include the following: a. Study of start-up, including transformer energization, shutdown, switching coordination, and other local area network switching events b. Study of STATCOM system protection and protection coordination c. Faults on the high-voltage (HV) and MV bus (single line-to-ground, phase-to- phase, and three-phase) d. Faults across the VSC, capacitors, and other equipment if used. e. Control interaction C.9.4 Insulation coordination study Overall insulation coordination should be verified by considering the results of 8.4 (dynamic over voltages, and fault and switching transients), including the impacts of lightning surges on the STATCOM equipment. This study [Insert Name of the SPV] 185 ……2026Transmission Service Agreement should determine and verify insulation levels, clearances, and arrester placement and ratings. C.9.5 Other Studies a) Grounding Study b) Protection coordination c) PLC/radio interference d) Magnetic field strength e) Other studies as applicable C.9.6 Software simulation models The TSP shall provide the latest following PSCAD and PSSE simulation model(s) and parameters to CEA/CTU/GRID-INDIA alongwith detailed documentation for the purpose of future simulation to adequately represent and model the proposed STATCOM system in the respective software: a. Stability model. TSP should provide a detailed STATCOM system dynamics model for use in (PSCAD and PSSE) power flow and stability simulation software The model detail should be appropriate and complete for positive- sequence power system simulation and analysis that is typically performed with power flow and transient stability programs. All appropriate control features for such analysis will be modeled, and necessary documentation on the theory and use of model should be provided. Further, a generic model, benchmarked to detailed STATCOM stability model, shall also be furnished for distribution. b. Transient model. TSP should provide a detailed STATCOM transients model for use in PSCAD. The model detail should be appropriate and complete for the transient response calculation of the STATCOM system. All appropriate control features for such analysis will be modeled, and necessary documentation on the theory and use of model should be provided. Further, a generic model, benchmarked to detailed STATCOM transient model, shall also be furnished for distribution. PSS/E files may be used for developing RTDS files/ models. For simulation of STATCOM in PSS/E file (load flow and dynamic) and PSCAD (Transient) model for STATCOM is required for study. TSP will share STATCOM models with CEA, CTU and Grid-India along with detailed documentation for above study purposes and simulations. For PSS/E, both Generic and User-defined models shall be shared by the TSP with the CEA, CTU and Grid-India. Generic model (PSS/E) response shall be benchmarked with user-defined model (PSS/E and PSCAD) to the extent possible by the TSP. Generic [Insert Name of the SPV] 186 ……2026Transmission Service Agreement models can be shared by the CEA, CTU and Grid-India with the concerned stakeholders/external party(ies) e. g. STUs etc. on need basis. For User Defined model, confidentiality shall be maintained by the CEA, CTU and Grid- India. For PSCAD, User Defined model shall be provided by the TSP for which confidentiality shall be maintained by the CEA, CTU and Grid-India. Both UDM (PSCAD and PSS/E) and Generic model (PSSE) shall be provided by OEMs to CEA/CTU/GRID-INDIA without any NDA (Non-Disclosure Agreement) C.9.7 Factory tests of controls The integrated nature of the performance of the STATCOM in an electrical grid requires the following tests: a. The TSP should perform factory simulator system tests for integrated control and protection system to ensure the proper operation of the same. The control system should be connected to a digital simulator with adequate representation of the electrical network for various conditions. The STATCOM system controller needs to be representative of control functions, including basic controllers but inclusive of supplementary controls, firing controls, and protective functions integrated into the controllers. TSP shall submit the Factory Acceptance Test (FAT) reports of STATCOM controls to CTU/RLDC. b. The simulator should provide an accurate network representation including network harmonic behavior, as well as synchronous condensers, power stations, generators (with AVRs), and pump storage schemes, existing HVDC, SVCs and STATCOMs, future SVCs and STATCOMs, FSC (fixed series capacitors), and shunt reactors/capacitors/filters. STATCOM system control function type tests on a simulator should include the following: - Verification of each control function. - Verification of control linearity. - Verification of control redundancy. - Verification of the monitoring system. - Verification of the protection system with reference to integrated protective functions included in the Controllers and firing controllers. - Verification of overall system performance for minor and major system disturbances. - Verification of processor loading of all digital controllers. [Insert Name of the SPV] 187 ……2026Transmission Service Agreement - Verification of STATCOM system parallel operation with other controls in the system and control Stability. - Verification of control equipment performance for auxiliary power supply voltage (AC and DC) and frequency variations (AC). - Routine production tests of all control functions, and separately of all protection functions. C.10.0 VISUAL MONITORING SYSTEM FOR WATCH AND WARD OF STATCOM STATION Visual monitoring system (VMS) for effective watch and ward of STACOM station premises covering the areas of entire switchyard, STATCOM building, Coupling Transformer, Cooling Towers and main gate, shall be provided. The TSP shall design, supply, erect, test and commission the complete system including cameras, Digital video recorder system, mounting arrangement for cameras, cables, LAN Switches, UPS and any other items/accessories required to complete the system. Features of VMS system shall be as those specified for main substation. The number of cameras and their locations shall be decided in such a way that any location covered in the area can be scanned. The cameras shall be located in such a way to monitor at least: a) Coupling Transformer, Mechanically Switched Reactors (MSRs) (if any) and Mechanically Switched Capacitors (MSCs) (if any), AC filter banks (if any). b) STATCOM Valve Hall, Cooling System, Electrical and Mechanical Auxiliary area. c) Entrance to STATCOM Station. d) All other Major Equipment (such as CB, CT, VT, SA etc.) The cameras can be mounted on structures, buildings or any other suitable mounting arrangement. C.11.0 Spares, Special Tools and Tackles Considering STATCOM as high technology proprietary equipment of the OEM, the TSP shall ensure necessary spares are procured to maintain the necessary reliability and availability of STATCOM station. Further all necessary special tools and tackles required for erection, testing, commissioning, and maintenance of equipment shall also be taken. [Insert Name of the SPV] 188 ……2026Transmission Service Agreement Annexure-I Contingency Cases for STATCOM A) N-1 Contingency Contingency at 765 kV level 1. Three Phase Fault close to 765 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Srikakulam 765 kV D/c line (fault persisted for 100 ms) 2. Single Phase to Ground Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping of one circuit of Pendurthi GH – Srikakulam 765 kV D/c line 3. Three Phase Fault close to 765 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Khammam-II 765 kV D/c line (fault persisted for 100 ms) 4. Single Phase to Ground Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit Pendurthi GH – Khammam-II 765 kV D/c line 5. Three Phase Fault close to 765 kV bus of Srikakulam S/s followed by tripping of one circuit of Srikakulam – Angul 765 kV D/c line (fault persisted for 100 ms) 6. Single Phase to Ground Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit of Srikakulam – Angul 765 kV D/c line 7. Three Phase Fault close to 765 kV bus of Srikakulam S/s followed by tripping of one circuit of Srikakulam – Kakinada GH 765 kV D/c line (fault persisted for 100 ms) 8. Single Phase to Ground Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit of Srikakulam – Kakinada GH 765 kV D/c line 9. Three Phase Fault close to 765 kV bus of Khammam-II S/s followed by tripping of one circuit of Khammam-II – Warangal New 765 kV D/c line (fault persisted for 100 ms) 10. Single Phase to Ground Fault close to 765 kV bus of Khammam-II S/s followed by single pole opening (100 ms) of the faulted phase and unsuccessful re- closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping one circuit of Khammam-II – Warangal New 765 kV D/c line Contingency at 400 kV level 11. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of [Insert Name of the SPV] 189 ……2026Transmission Service Agreement one circuit of Pendurthi GH – Maradam 400 kV (Quad) D/c line (fault persisted for 100 ms) 12. Single Phase to Ground Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping of one circuit of Pendurthi GH – Maradam 400 kV (Quad) D/c line 13. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of one circuit of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line (fault persisted for 100 ms) 14. Single Phase to Ground Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. tripping of one circuit of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line 15. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of one 765/400kV ICT at Pendurthi GH (fault persisted for 100 ms) 16. Three Phase Fault close to 400 kV bus of Pendurthi GH followed by tripping of 1 GW demand at Pendurthi GH (fault persisted for 100 ms) – Load Throwover case B) N-1-1 Contingency Contingency at 765 kV level 17. Case 1 & 2 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Srikakulam 765 kV D/c line) and successful re-closure (dead time 1 second) 18. Case 3 & 4 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Khammam-II 765 kV D/c line) and successful re-closure (dead time 1 second) 19. Case 5 & 6 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Srikakulam – Angul 765 kV D/c line) and successful re-closure (dead time 1 second) 20. Case 7 & 8 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Srikakulam S/s followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Srikakulam – Kakinada GH 765 kV D/c line) and successful re-closure (dead time 1 second) 21. Case 9 & 10 (consider as separate cases) + Single Phase Fault close to 765 kV bus of Khammam-II S/s followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Khammam-II – Warangal New 765 kV D/c line) and successful re-closure (dead time 1 second) Contingency at 400 kV level [Insert Name of the SPV] 190 ……2026Transmission Service Agreement 22. Case 11 & 12 (consider as separate cases) + Single Phase Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Maradam 400 kV (Quad) D/c line) and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. 2nd ckt of Pendurthi GH – Maradam 400 kV (Quad) D/c line 23. Case 13 & 14 (consider as separate cases) + Single Phase Fault close to 400 kV bus of Pendurthi GH followed by single pole opening (100 ms) of the faulted phase (2nd ckt of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line) and unsuccessful re-closure (dead time 1 second) followed by 3-pole opening (100 ms) of the faulted line i.e. 2nd ckt of Pendurthi GH – Kalpakka 400 kV (Quad) D/c line [Insert Name of the SPV] 191 ……2026Transmission Service Agreement SPECIFIC TECHNICAL REQUIREMENTS FOR COMMUNICATION The communication requirement shall be in accordance to CEA (Technical Standards for Communication System in Power System Operations) Regulations, 2020, CEA (Technical Standards for Construction of Electrical Plants and Electric Lines) Regulations, 2022, CERC (Communication System for inter-State transmission of electricity) Regulations, 2017, CEA (Cyber Security in Power Sector) Guidelines, 2021, CERC Guidelines on “Interface Requirements” 2024 and all above documents as amended from time to time. The communication services viz. SCADA, AGC (wherever applicable), VoIP, AMR and PMU have been identified as critical services and therefore shall be provisioned with 2+2 redundancy i.e. 2 channels for Main Control Centre and 2 channels for Backup Control Centre. In order to meet this requirement, suitable redundancy at port and card level need to be ensured by the TSP to avoid any single point of failure which may lead to interruption in real-time grid operation. PMU to PDC communication (wherever required) shall be through 2 channels to the PDC (main) as there is no backup PDC at present. Accordingly, all the hardware for communication services of station as stated above shall support dual redundancy for data transmission of station to respective main and backup RLDCs The complete ISTS communication system commissioned by TSP under the RFP shall be the asset of ISTS and shall be available for usage of ISTS requirements as suggested by CTU from time to time. In order to meet the requirement for grid management and operation of substations, Transmission Service Provider (TSP) shall provide the following: C.1.0 FOTE Requirement for line bays at Pendurthi (Vizag) S/s (I) TSP shall supply install & commission FODP with minimum 288 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. (II) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum six (6) directions with MSP (Multiplex Section Protection – 1+1). These directions shall exclude protected (1+1) local patching among equipment (if any). Communication Equipment shall be provided with necessary interfaces [Insert Name of the SPV] 192 ……2026Transmission Service Agreement to meet the voice and data communication requirement among Pendurthi (Vizag) S/s, Srikakulam S/s, Khammam-II S/s, Kalpakka S/s and Maradam S/s. The suitable DC Power Supply and backup to be provided for communication equipment. (III) FOTE & FODP Eq can be accommodated in same panel to optimize space. (IV) TSP shall deploy Cyber Security System in compliance with CEA (Cyber Security in Power Sector) Guidelines, 2021 and CEA (Cyber Security in Power Sector) Regulation, from its date of publication/ notification and their amendments thereof. (V) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP. C.2.0 FOTE Requirement for line bays at Srikakulam S/s i) TSP shall supply install & commission FODP with minimum 144 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum three (3) directions with MSP (Multiplex Section Protection – 1+1). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement between Srikakulam S/s and Pendurthi (Vizag) and local patching with control room FOTE. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE/FODP panel shall be installed in the new Bay Kiosk/Switchyard Panel Room (SPR)/Relay panel Room. The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of Srikakulam S/s which shall be communicating with respective control center. TSP to provide necessary FODP sub rack / Splice trays/ Patch [Insert Name of the SPV] 193 ……2026Transmission Service Agreement cords etc. and optical interfaces/equipment in the existing FOTE/FODP panels in control room for integration with the existing FOTE for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. Alternatively, The TSP may integrate the FOTE under the present scope with existing FOTE in the nearby Kiosk connected to the control room FOTE (if available with spare direction). For this purpose, TSP shall provide necessary FODP sub rack / Splice trays/ Patch cords etc. and suitable optical interfaces/ equipment in the existing FOTE/FODP panels in another Kiosk (SPR). iv) FOTE & FODP Eq can be accommodated in same panel to optimize space. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP. C.3.0 FOTE Requirement for line bays at Warangal New S/s i) TSP shall supply install & commission FODP with minimum 144 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum three (3) directions with MSP (Multiplex Section Protection – 1+1). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement between Khammam-II S/s and Warangal New S/s and local patching with control room FOTE. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE/FODP panel shall be installed in the new Bay Kiosk/Switchyard Panel Room (SPR)/Relay panel Room. The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of Warangal New S/s which shall be communicating with respective control center. TSP to provide necessary FODP sub rack / Splice trays/ Patch [Insert Name of the SPV] 194 ……2026Transmission Service Agreement cords etc. and optical interfaces/equipment in the existing FOTE/FODP panels in control room for integration with the existing FOTE for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. Alternatively, The TSP may integrate the FOTE under the present scope with existing FOTE in the nearby Kiosk connected to the control room FOTE (if available with spare direction). For this purpose, TSP shall provide necessary FODP sub rack / Splice trays/ Patch cords etc. and suitable optical interfaces/ equipment in the existing FOTE/FODP panels in another Kiosk (SPR). iv) FOTE & FODP Eq can be accommodated in same panel to optimize space. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP C.4.0 FOTE Requirement for line bays at Khammam-II S/s i) TSP shall supply install & commission FODP with minimum 240 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum five (5) directions with MSP (Multiplex Section Protection – 1+1). These directions shall exclude protected (1+1) local patching among equipment (if any). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement among Khammam-II S/s, Pendurthi(Vizag) S/s, Khammam(existing) S/s and Warangal New S/s. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE & FODP Eq can be accommodated in same panel to optimize space. [Insert Name of the SPV] 195 ……2026Transmission Service Agreement iv) TSP shall deploy Cyber Security System in compliance with CEA (Cyber Security in Power Sector) Guidelines, 2021 and CEA (Cyber Security in Power Sector) Regulation, from its date of publication/ notification and their amendments thereof. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP C.5.0 FOTE Requirement for line bays at Khammam (existing) S/s i) TSP shall supply install & commission FODP with minimum 144 Fiber capacity along with panel and approach Cable (48F each) with all associated hardware fittings from gantry tower to Control Room for all the incoming lines envisaged under the present scope. ii) TSP shall supply, install & commission One or more STM-16 (FOTE) equipment alongwith panel/s supporting minimum three (3) directions with MSP (Multiplex Section Protection – 1+1). Communication Equipment shall be provided with necessary interfaces to meet the voice and data communication requirement between Khammam-II S/s and Khammam (existing) S/s and local patching with control room FOTE. The suitable DC Power Supply and backup to be provided for communication equipment. iii) FOTE/FODP panel shall be installed in the new Bay Kiosk/Switchyard Panel Room (SPR)/Relay panel Room. The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of Khammam (existing) S/s which shall be communicating with respective control center. TSP to provide necessary FODP sub rack / Splice trays/ Patch cords etc. and optical interfaces/equipment in the existing FOTE/FODP panels in control room for integration with the existing FOTE for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. Alternatively, The TSP may integrate the FOTE under the present scope with existing FOTE in the nearby Kiosk connected to the control room FOTE (if available with spare direction). For this purpose, TSP shall provide necessary FODP [Insert Name of the SPV] 196 ……2026Transmission Service Agreement sub rack / Splice trays/ Patch cords etc. and suitable optical interfaces/ equipment in the existing FOTE/FODP panels in another Kiosk (SPR). iv) FOTE & FODP Eq can be accommodated in same panel to optimize space. v) The maintenance of all the communication equipment and software including FOTE, FODP, PMU, approach cable, DCPS alongwith Battery Bank & Cyber Security System shall be the responsibility of TSP C.6.0 OPGW requirement for LILO of Kalpakka – Maradam 400 kV D/c line at Pendurthi i) On LILO of Kalpakka – Maradam 400 kV D/c line at Pendurthi, TSP shall supply, install & commission OPGW and earthwire as per Tower Configurations: a. Loop-In and Loop out Ckt on Single Towers: Two (2) no. OPGW cable containing 48 Fibres (48F) to be installed & commissioned by the TSP on both the Earthwire peaks. b. Loop-In and Loop out Ckt on Two separate Towers: One (1) no. OPGW cable containing 48 Fibres (48F) on one earthwire peak & conventional earthwire on other E/W peak for both Loop In and Loop Out Lines. ii) The TSP shall install OPGW cables from gantry of Pendurthi (Vizag) station up to the LILO tower with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at Pendurthi (Vizag) station. The LILO portion length is 20 kms (approx.). After LILO, if fiber length for links Pendurthi (Vizag) station to Kalapakka S/s and Pendurthi (Vizag) station to Maradam S/s is above 225 kms then repeater shall be envisaged, otherwise line can be managed as a repeater less link. iii) TSP shall finalize the location of repeater station depending upon the actual site conditions. Further TSP shall comply to the requirements mentioned as per Appendix-F.1 [Insert Name of the SPV] 197 ……2026Transmission Service Agreement iv) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP Note: Necessary optical interfaces/ FOTE shall be provided by TSP in the FOTE of Kalapakka S/s and Maradam S/s as per link budget requirement due to LILO. C.7.0 Khammam-II – Pendurthi (Vizag) 765 kV D/c line (I) On Khammam-II – Pendurthi (Vizag) 765 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. (II) The TSP shall install this OPGW from gantry of Khammam-II S/s up to the gantry of Pendurthi (Vizag) S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 350 kms (approx.), where repeater may be required to meet the link budget requirement of Khammam-II – Pendurthi (Vizag) link. The same shall be provided by TSP. (III) TSP shall finalize the location of repeater station depending upon the actual site conditions. Further TSP shall comply to the requirements mentioned as per Appendix-F.1 (IV) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. C.8.0 Pendurthi (Vizag) – Srikakulam 765 kV D/c line i) On Pendurthi (Vizag) – Srikakulam 765 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. ii) The TSP shall install this OPGW from gantry of Pendurthi (Vizag) S/s up to the gantry of Srikakulam S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 200 kms (approx.), where repeater may not be required to meet the link budget requirement of Pendurthi (Vizag) – Srikakulam link. iii) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. [Insert Name of the SPV] 198 ……2026Transmission Service Agreement C.9.0 Khammam-II – Warangal New 765 kV D/c line i) On Khammam-II – Warangal New 765 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. ii) The TSP shall install this OPGW from gantry of Khammam-II S/s up to the gantry of Warangal New S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 100 kms (approx.), where repeater may not be required to meet the link budget requirement of Khammam-II – Warangal New link. iii) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. C.10.0 Khammam-II – Khammam (existing) 400 kV D/c line i) On Khammam-II – Khammam (existing) 400 kV D/c line, TSP shall supply, install & commission One (1) no. OPGW cable containing 48 Fibres (48F) on one E/W peak and conventional earth wire on other E/W peak. ii) The TSP shall install this OPGW from gantry of Khammam-II S/s up to the gantry of Khammam (existing) S/s with all associated hardware including Vibration Dampers, mid-way & gantry Joint Boxes (called OPGW Hardware hereafter) and finally terminate in Joint Boxes at end Substations. The transmission line length is 20 kms (approx.), where repeater may not be required to meet the link budget requirement of Khammam-II – Khammam (existing) link. iii) Maintenance of OPGW Cable & OPGW Hardware shall be responsibility of TSP. C.11.0 Specific Requirement for Phasor Measurement Units (PMUs) TSP shall supply, install and commission required No. of Phasor Measurement Units (PMUs) as per the “Guidelines on Unified Philosophy for placement of PMUs in Indian Grid” (along with all amendments if any) issued vide CEA letter No. CEA-PS-14-12/9/2024-PSETD Division dated 19.03.2025 for the scope of this RFP. The PMUs shall be provided with LAN switch and shall connect with LAN switch of control room of respective substations/ generating stations with Fibre Optic cable. The PMUs shall be connected with [Insert Name of the SPV] 199 ……2026Transmission Service Agreement the FOTE at Substation/ generating stations for onwards data transmission to the PDC (Phasor Data Concentrator) located at respective RLDC. Configuration work in existing PDC at RLDC for new PMU integration shall be done by respective RLDC, however all the necessary support in this regard shall be ensured by TSP. The maintenance of all the PMUs and associated equipment shall be the responsibility of TSP. Note: Existing Station owner/s to provide necessary support to integrate different equipment and applications of new extended bays with the existing substation e.g. Communication (through FOTE), Voice etc. for smooth operation and monitoring of new added grid elements. C.12.0 Specific Requirement for UNMS Integration of FOTE Communication system integration in UNMS/CSMS TSP is to ensure integration of communication system into UNMS/CSMS as per following: “The new communication equipment/ system under the present scope shall be compatible for integration with existing regional level NMS system/ Centralized Supervision & Monitoring System (CSMS) i.e. Regional UNMS. The local configuration of the new communication equipment/ system at the station end shall be the responsibility of TSP as per followings. The configuration work in the existing centralized NMS/ UNMS at Control center end, for integration of new Communication equipment/ system shall be done by Regional ULDC Team/ NMT, however all the necessary support in this regard shall be ensured by TSP. Requirement for integration of Communication Equipment/ system with Regional UNMS: 1. TSP shall ensure that NMS/EMS/NE supplied by them is NBI compliant and all FCAPS functionality is supported in the NBI such as NE Inventory, Hardware Inventory– Shelf/Slot/Card/SFP/Port, Topology, Protections, Alarms, Performance-real time & periodic, Performance KPI parameters (E-1, STM, Ethernet), Remote Configuration, Cross Connects, Trails & Circuits, Services Provisioning (NE), E-1, STM, Ethernet, TX & RX Trace, loop back and details are published in the NBI guide for the configuration parameters. [Insert Name of the SPV] 200 ……2026Transmission Service Agreement 2. TSP shall be obliged to provide/share all necessary documentations such as NBI Guide/MIB/IDL/WSDL/API files etc. for onward integration of their NMS/EMS/NE with regional UNMS. 3. The following support shall be provided by TSP for integration of their supplied equipment with regional UNMS: • Enabling & activating NBI license in their EMS/NMS and providing NBI login access along with User credentials • Assist in verifying NBI Connectivity with UNMS vendor for the successful communication and retrieval of data. 4. Assist in troubleshooting (if required) for NBI connectivity along with UNMS vendor for the communication and retrieval of data. For standalone NE which is 5. not integrated with any EMS/NMS, TSP shall provide modality of complete FCAPS data acquisition as above through industry standard programmatic methods and provide the CLI command manual.” Appendix-F.1 Repeater Requirements  If the repeater location is finalized in the Control Room of a nearby substation, TSP shall provide OPGW to accommodate all the fibers in main transmission line on a single Earthwire peak with OPGW Hardware & mid- way Joint Boxes etc. of the line crossing the main line and required approach Cable to accommodate all the OPGW fibers with all associated hardware fittings, to establish connectivity between crossing point of main transmission line up to the repeater equipment in substation control room. TSP shall co-ordinate for Space & DC power supply sharing for repeater equipment. TSP shall provide FODP, FOTE (with STM-16 capacity) with suitable interfaces required for link budget of respective link. OR  If the repeater location is finalized in the nearby substation premises, the TSP shall identify the Space for repeater shelter in consultation with station owner. Further TSP shall provide OPGW to accommodate all the fibers in main transmission line on a single Earthwire peak with OPGW Hardware & [Insert Name of the SPV] 201 ……2026Transmission Service Agreement mid-way Joint Boxes etc. of the line crossing the main line and required approach Cable/UGFO to accommodate all the OPGW fibers with all associated hardware fittings, to establish connectivity between crossing point of main transmission line up to the substation where the repeater shelter is to be housed. TSP shall provide repeater shelter along with FODP, FOTE (with STM-16 capacity) with suitable interfaces require for link budget of respective link, reliable power supply provisioning for AC and DC supply, battery bank, Air Conditioner and other associated systems. OR  If the repeater location is finalized on land near the transmission tower. TSP shall make the provisions for Land at nearby tower for repeater shelter. Further TSP shall provide required approach Cable to accommodate all the OPGW fibers with all associated hardware fittings to establish connectivity up to the location of repeater shelter. TSP shall provide repeater shelter along with FODP, FOTE (with STM-16 capacity) with suitable interfaces require for link budget of respective link, reliable power supply provisioning for AC and DC supply, battery bank, Air Conditioner and other associated systems Maintenance of OPGW Cable and OPGW Hardware, repeater equipment & items associated with repeater shelter shall be the responsibility of TSP. [Insert Name of the SPV] 202 ……2026Transmission Service Agreement Figure F.1 [Insert Name of the SPV] 203 ……2026Transmission Service Agreement C.13.0 PLCC and PABX: Power line carrier communication (PLCC) equipment complete for speech, tele-protection commands and data channels shall be provided on each transmission line. The PLCC equipment shall in brief include the following: - - Coupling device, Coupling filters line traps, carrier terminals, protection couplers, HF cables, PABX (if applicable) and maintenance and testing instruments. - At new substation, a telephone exchange (PABX) of 24 lines shall be provided at as means of effective communication among various buildings of the substation, remote end substations and with control centres (RLDC/ SLDC) etc. - Coupling devices shall be suitable for phase-to-phase coupling for 400 kV Transmission lines. The pass band of coupling devices shall have sufficient margin for adding communication channel in future if required. Necessary protection devices for safety of personnel and low voltage part against power frequency voltages and transient over voltage shall also be provided. - The line traps shall be broad band tuned suitable for blocking the complete range of carrier frequencies. Line Trap shall have necessary protective devices such as lightning arresters for the protection of tuning device. Decoupling network consisting of line traps and coupling capacitors may also be required at certain substation in case of extreme frequency congestion. - The carrier terminals shall be of single side-band (SSB) amplitude modulation (AM) type and shall have 4 kHz band width. PLCC Carrier terminals and Protection couplers shall be considered for both ends of the line. - PLCC equipment for all the transmission lines covered under the scheme shall be provided by TSP. PLCC to be provided for following lines under present scope: Sl. No Line name PLCC configuration 1. 1 set Analog PLCC + 1 set Digital Pendurthi (Vizag) – Protection Coupler for each circuit Srikakulam 765 kV D/c at both ends. line 2. 1 set Analog PLCC + 1 set Digital Khammam-II – Warangal Protection Coupler for each circuit New 765 kV D/c line at both ends. 3. 1 set Analog PLCC + 1 set Digital Khammam-II – Pendurthi Protection Coupler for each circuit (Vizag) 765 kV D/c line at both ends. [Insert Name of the SPV] 204 ……2026Transmission Service Agreement 4. 1 set Analog PLCC + 1 set Digital Khammam-II – Khammam Protection Coupler for each circuit (existing) 400 kV D/c line at both ends. - TSP shall provide/ undertake necessary addition/ modification/ shifting/ re- commissioning etc. of PLCC equipment due to LILO of transmission lines: Sl. No Line name PLCC configuration 1. 1 set Analog PLCC + 1 set Kalpakka – Pendurthi Digital Protection Coupler for (Vizag) 400 kV D/c line each circuit at both ends. [formed after LILO] 1 set Analog PLCC + 1 set Pendurthi (Vizag) – Digital Protection Coupler for 2. Maradam 400kV D/c line each circuit at both ends. [formed after LILO] - Further, CVT and Wave trap for all 765 kV and 400 kV line bays under present scope shall be provided by TSP. - All other associated equipment like cabling, coupling device and HF cable shall also be provided by the TSP. - Two (2) sets of 48 V battery banks for PLCC and communication equipment shall be provided at each new Substation with at least 10-hour battery backup and extended backup, if required. [Insert Name of the SPV] 205 ……2026Transmission Service Agreement Frequently Asked Queries: 1.0 Transmission Line: 1.1 Please clarify that whether shutdowns for crossing of existing transmission lines of POWERGRID/STUs/ Power Evacuation Lines from Generation Plants/ Any other Transmission Licensee will be given to TSP on chargeable basis or free of cost. Reply: Shutdowns for crossing of existing transmission lines of POWERGRID/ STUs/ Power Evacuation Lines from Generation Plants/ Any other Transmission Licensee will be given to TSP by the concerned owner of the lines as per their own terms and conditions. As far as shutdown of ISTS lines are concerned the same can be availed by approaching respective Regional Power Committee. 1.2 We understand that the suggested swing angle criteria are applicable for Suspension Insulator in Suspension Tower. Further, you are requested to provide similar swing angle and clearance criteria for Pilot Insulator with Jumper and Jumper. Reply: It is clarified that the swing angle criteria (as mentioned in RFP) for transmission lines is applicable for Suspension Insulator in Suspension Tower. Further, as per Clause 3.0 of Specific Technical Requirements for transmission lines, Transmission service Provider (TSP) shall adopt any additional loading/design criteria for ensuring reliability of the line, if so desired and /or deemed necessary. 1.3 We request you to kindly allow that use of diamond configuration at Power line crossings and the existing owner of the lines may be directed to allow the same for the successful bidders. Reply: Power line crossing including Diamond configuration is the responsibility of the TSP. TSP shall formally submit the profile of the crossing section to the owner of the existing line suggesting proposed crossing alternatives. The crossing will have to be carried out as per approval of owner of the existing line. 1.4 It is requested you to kindly provide present status of Forest Clearances if any transmission line corridor area falling in wildlife forest / reserve forest/ mangroves Reply: Based on the preliminary route survey, the process of initiation of forest clearance for the forest stretches, if any, enroute the proposed line alignment will be initiated by way of writing letters to the concerned [Insert Name of the SPV] 206 ……2026Transmission Service Agreement authority (ies). However, it may be noted that it will be the responsibility of TSP for obtaining forest clearance for the forest stretches as provided in the survey report and also for any forest area encountered during detailed survey. 1.5 For transmission line, no special requirement is specified for type of Insulator and creepage in RFP document. Hence it is understood that bidder can decide the type of insulator along with creepage requirement based on general CEA regulations and relevant standards. Kindly confirm. Reply: The minimum specific creepage distances shall be decided for the site pollution severity in the area of installation keeping in mind further increase in pollution during life of the line. It shall be as per CEA regulations and relevant standards. However, the tower shall be designed considering the porcelain insulators with creepage factor of 31 mm/kV irrespective of type of insulator used. 2.0 Substation 2.1 We understand that space for storage of O&M spare shall be provided by the existing owner within the station boundary without any cost. Kindly confirm. Reply: Space for storage of O&M spares shall be arranged by TSP on its own. 2.2 We presume that the O&M for the end Termination bays will be in the scope of the TSP and TSP shall not be liable for any payment towards O&M to the existing owner of the substation. Kindly confirm. Reply: Operation and maintenance of the bays is solely the responsibility of the TSP. Further, TSP shall follow CEA’s “Operation and Maintenance (O&M) guidelines and Standard Format for Memorandum of Understanding between New TSP and Existing TSP” issued by CEA vide its letter No. I/28514/2023 dated 22.06.2023. 2.3 With reference to subject scheme of existing sub-station, we assumed following scope of work: (a) We assumed internal road is available and need not to be consider in the present scope of work. (b) Drainage is available and need not to consider in the present scope of work. (c) Cable trench extension in adjacent to Main cable trench only under present scope of work. (d) Levelled area being provided by developer for bay extension. [Insert Name of the SPV] 207 ……2026Transmission Service Agreement Reply: Regarding requirement of internal road, drainage, cable trench, leveling of the bay extension area, bidder is advised to visit site and acquaint themselves with the provisions/facilities available at substation. 2.4 Kindly provide the soil investigation report of soil parameters of existing substation. Reply: Bidder is advised to visit the substation site and ascertain the requisite parameters. 2.5 Kindly confirm, energy accounting of aux. power consumption. Whether it will be on chargeable basis or part of transmission loss. Reply: It will be on a chargeable basis. 2.6 We understand that VMS requirement is for unmanned stations only. For Manned stations VMS is not compulsory. Reply: VMS shall be provided in line with requirements of RfP document. 2.7 It is understood that Construction water and power shall be provided free of cost to TSP by the respective substation owner for construction of new bays. Reply: Arrangement of construction power and water is in the scope of TSP. 2.8 It is understood that the existing fire hydrant system shall be extended by the TSP for bay extension. Reply: Existing fire hydrant system shall be extended from existing system (if required) 2.9 Please clarify the Status of land acquisition for new Substations. Whether the lands have been acquired by BPC and will be transferred to TSP. Reply: The acquisition of land for new substation is in the scope of TSP. 2.10 We understood that no any dedicated metering CT and CVT required for Line/feeders. Further, we understood that requisite Energy meters for various 765 kV, 400 kV and 220 kV Feeders shall be provided and installed by CTU free of cost to TSP. Reply: Dedicated metering CT and CVT are not required for line/feeders. Metering core of existing CT/CVT can be used provided accuracy class matches with metering requirement. Requisite Special Energy Meters shall be provided and installed by CTU at the cost of TSP in C and P panel subject to space availability, else, in separate metering panel (to be provided by TSP at its cost). 2.11 A draft copy of the Connection Agreement may be furnished. A draft copy of the Connection Agreement may be furnished. Reply: Web page link https://www.ctuil.in/formats_gna_transition 2.12 Please clarify whether the spare 765 kV single phase Reactor unit for Bus reactor shall be provided with 1ph 765 kV CB. [Insert Name of the SPV] 208 ……2026Transmission Service Agreement Reply: As per RfP, the spare 1-Ph reactor unit shall be utilized for all the bus and switchable line reactor banks (including for future reactor banks). Hence, 1ph 765 kV CB shall also be provided with spare 1-Ph reactor for utilizing with bus reactor as well as switchable line reactor. 2.13 It is understood that existing busbar protection has provision for future bays and also PUs are available for future bays. BPC to confirm availability of CU and PU for bays under present scope of work at existing substations. BPC may kindly confirm availability of communication ports for integrating new PUs with the existing CUs at existing substations. Reply: Bus Bar Protection with Central Unit (CU) is required for the new bus section as specified in RfP. Peripheral Units (PUs) shall be provided by the respective bay owner. Further, augmentation/replacement of existing CU, if required, to meet the system requirement shall also be provided for proper functioning of bus bar protection. 2.14 For SCADA, it is understood that necessary process I/O shall be available for future bays and accordingly license for same. BPC to confirm. Reply: Necessary process I/O along with license shall be in the scope of the successful bidder. 2.15 No separate FF system is envisaged under the present scope of work for existing substation. BPC to confirm. Reply: Existing fire-fighting systems shall be extended to meet the additional requirements under present scope. 2.16 PLCC for 220 kV Lines are not under the scope of TSP. BPC to Confirm.It is requested to provide Type of Coupling for 220 kV Transmission Lines under present scope. Reply: PLCC for 220 kV line is in the scope of developer of the line. Inter circuit coupling for 220 kV D/C and phase to phase coupling for 220 kV S/C shall be applicable for PLCC. 2.17 BPC is requested to confirm the availability of space in the existing control rooms at existing substation for execution of extension work under current project. Reply: Switchyard Panel Rooms are generally required for AIS type substation and relay room are required for GIS type substation. Further, if needed, the control room shall be augmented as per requirement. 3.0 Communication 3.1 What are the usage of OPGW, FOTE, PMU etc. under communication [Insert Name of the SPV] 209 ……2026Transmission Service Agreement requirement of RFP? Reply: User shall be responsible for providing compatible equipment along with appropriate interface for uninterrupted communication with the concerned control center and shall be responsible for successful integration with the communication system provided by CTU. Communication systems e.g. OPGW, FOTE etc. and PMU are required for grid operation through RLDC/SLDC, speech communication, tele- protection and tele-metering. 3.2 Is space for installation of communication panels are provided to TSP in existing Substations incase new bays are in the scope of TSP? Reply: The space related issues are deliberated in the RfP itself. TSP to install FOTE/FODP panels in the new Bay Kiosk (Switchyard Panel Room (SPR)) / Bay Kisok/ Relay Panel Room (in case of GIS S/s). Further, TSP to connect and integrate the proposed FOTE with the existing FOTE in the control room to complete the communication path upto RLDC. In Case 132 kV Substation TSP shall accommodate the said panels either by extension of existing control room or other arrangements. 3.3 How is the OPGW laying done in case of LILO lines? Reply: In case LILO lines are on same towers (e.g. both Line in and Line Out portion are on same towers, generally done LILO of S/C lines). Then 2x48F OPGW shall be required to install by TSP on both earthwire peak on 400 kV and 765 kV lines where two E/W peaks are available. On 220 kV and 132 kV lines where only one E/W peak is available TSP to install one No. 96F OPGW. Incase LILO lines are on different towers (e.g. both Line In and Line Out portion are on different towers, generally done LILO of D/C lines). Then 1x48F OPGW shall be required to install by TSP on one earthwire peak and conventional earthwire on second earthwire peak, on both Line In and Line Out portion towers of 400 kV and 765 kV lines. On 220 kV and 132 kV lines where only one E/W peak is available TSP to install one No. 48F OPGW in place of conventional earthwire. 3.4 How is the OPGW laying done in case Multi circuit Towers? Reply: In case two different lines are using common multi circuit portion for some distance (originating from different stations, may be terminating [Insert Name of the SPV] 210 ……2026Transmission Service Agreement on same or on different stations). Two No. 48F OPGW to be installed on both E/W peaks for common M/C portion of 765 kV and 400 kV lines. Incase 220/132 kV lines using multi circuit portion where single E/W peak is available one No. 96F may be installed for common multi circuit portion. 3.5 How PMUs are integrated for new bays at existing Substations? Reply: PMU data of new bays to be provided in the ethernet port of switch at control room and thereafter to be connected with existing FOTE of existing substation to send data to PDC of RLDC by TSP. These PMUs shall be provided with GPS/NavIC clock and LAN switch and shall connect with LAN switch of control room of respective substations with Fiber Optic cable. In this regard, the “Guidelines on Unified Philosophy for placement of PMUs in Indian Grid” issued vide letter No. CEA-PS-14-12/9/2024-PSETD Division dated 19.03.2025 shall be followed. 3.6 Is Spare direction available in existing FOTE for integration with new bay kiosk FOTE Reply: The FOTE under present scope shall be integrated by TSP with the existing FOTE at control room of substation for onwards data transmission. In case spare optical direction is not available in the existing FOTE at the control room, the TSP shall coordinate with station owner to reconfigure the directions in existing FOTE at control room. 3.7 What is the distance from LILO point to proposed substation for feasibility of repeater station? Reply: Tentative Location of LILO point shall be as per survey report of BPC however, exact location to be ascertained after detailed survey by TSP. 3.8 What is the make and model of existing OPGW in case LILO of main line at new substation? Reply: All OPGW (alongwith optical fibers) meet Central Electricity Authority (Technical Standards for Communication System in Power System Operations) Regulations, 2020 and bidder shall install OPGW accordingly. 3.9 In case of LILO of existing line at new substation who shall provide PMUs at existing substation bays? Reply: TSP shall provide the PMUs for the scope under the RfP in compliance of the “Guideline on Unified Philosophy for placement of [Insert Name of the SPV] 211 ……2026Transmission Service Agreement PMUs in Indian Grid” issued vide letter No. CEA-PS-14-12/9/2024- PSETD Division dated 19.03.2025. 4.0 Planning : 4.1 Whether the Project/ Elements are eligible for early commissioning incentive as per MoP, GoI order dated 15.07.2015. Reply: Commissioning is to be done as per the timeline mentioned in RfP. However, early commissioning shall be treated as per applicable CERC Regulations/orders. [Insert Name of the SPV] 212 ……2026Transmission Service Agreement [Insert Name of the SPV] 213 ……2026Transmission Service Agreement Schedule: 2 Scheduled COD [Note: As referred to in the definition of “Element”, “Scheduled COD”, and in Articles 3.1.3 (c), 4.1 (b) and 4.3 (a) of this Agreement] Inter-Regional Strengthening between SR Grid and WR Grid Element(s) which are Schedule % of Quoted pre-required d COD as Transmission for declaring per Charges Sl. Name of the Transmission the Gazette recoverable on No. Element commercial Notificati Scheduled COD operation on of the Element (COD) of the of the Project respective Element 1. Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) Element at GIS substation with 1x330 Sl. No. 2, 3, MVAr (765 kV) bus reactor with 4, 5, 6 , 7 & space provision for 8 establishment of 220 kV switchyard 2. ± 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi Element at (Vizag) GIS with control Sl. No. 1, 3, switching arrangement for 4, 5, 6, 7 & 8 proposed 1x330 MVAr bus 30 months 100 reactor 3. Pendurthi (Vizag) – Srikakulam Element at 765 kV D/c line with 330 MVAr Sl. No. 1, 2, SLR (convertible) at Srikakulam 4, 5, 6, 7 & 8 end on both circuits 4. LILO of Kalpakka – Maradam Element at 400 kV (quad) D/c line at Sl. No. 1, 2, Pendurthi 3, 5, 6, 7 & 8 5. Establishment of 3x1500 MVA, Element at 765/400 kV Khammam-II Sl. No. 1, 2, substation with 1x330 MVAr 3, 4, 6, 7 & 8 [Insert Name of the SPV] 214 ……2026Transmission Service Agreement Element(s) which are Schedule % of Quoted pre-required d COD as Transmission for declaring per Charges Sl. Name of the Transmission the Gazette recoverable on No. Element commercial Notificati Scheduled COD operation on of the Element (COD) of the of the Project respective Element (765 kV) bus reactor with space provision for establishment of 220 kV switchyard 6. Khammam-II – Warangal New Element at 765 kV D/c line Sl. No. 1, 2, 3, 4, 5 ,7 & 8 7. Khammam-II – Pendurthi Element at (Vizag) 765 kV D/c line with 330 Sl. No. 1, 2, MVAr SLR (convertible) at both 3, 4, 5, 6 & 8 ends on both circuits 8. Khammam-II – Khammam Element at (existing) 400 kV (quad) D/c line Sl. No. 1, 2, 3, 4, 5, 6 & 7 The payment of Transmission Charges for any Element, irrespective of its successful commissioning on or before its Scheduled COD, shall only be considered after successful commissioning of the Element(s), which are prerequired for declaring the commercial operation of such Element as mentioned in the above table. Scheduled COD for the Project is: 30 months from the date of SPV transfer. [Note: List of Element(s) along with the critical Element(s) to be provided by CEA] [Insert Name of the SPV] 215 ……2026Transmission Service Agreement Schedule: 3 Safety Rules and Procedures [Note: As referred to in Articles 5.6 of this Agreement] 1: Site Regulations and Safety: The TSP shall establish Site regulations within sixty (60) days from fulfilment of conditions subsequent, as per Prudent Utility Practices setting out the rules to be observed till expiry of the Agreement at the Site and shall comply therewith. Such Site regulations shall include, but shall not be limited to, rules in respect of security, safety of the Project, gate control, sanitation, medical care, and fire prevention, public health, environment protection, security of public life, etc. Copies of such Site regulations shall be provided to the Nodal Agency and the CEA for the purpose of monitoring of the Project. 2: Emergency Work: In cases of any emergency, the TSP shall carry out all necessary remedial work as may be necessary. If the work done or caused to be done by any entity , other than the TSP, the TSP shall, reimburse the actual costs incurred, to the other Party carrying out such remedial works. 3: Site Clearance: In the course of execution of the Agreement, the TSP shall keep the Site reasonably free from all unnecessary obstruction, storage, remove any surplus materials, clear away any wreckage, rubbish and temporary works from the Site, and remove any equipment no longer required for execution of the Agreement. After completion of all Elements of the Project, the TSP shall clear away and remove all wreckage, rubbish and debris of any kind from the Site, and shall leave the Site clean and safe. 4: Watching and Lighting: The TSP shall provide and maintain at its own expense all lighting, fencing, and watching when and where necessary for the proper construction, operation, maintenance / repair of any of the Elements of the Project, or for the safety of the owners and occupiers of adjacent property and for the safety of the public, during such maintenance / repair. [Insert Name of the SPV] 216 ……2026Transmission Service Agreement Schedule: 4 Computation of Transmission Charges 1.1 General The Monthly Transmission Charges to be paid to the TSP for providing Transmission Service for any Contract Year during the term of the Agreement shall be computed in accordance with this Schedule and paid as per Sharing Regulations. Illustration regarding payment of Transmission Charges under various scenarios (considering definitions of Contract Year, Expiry Date & Monthly Transmission Charges above) is as below: - Illustration-1: In case the Project Elements achieve COD as per Schedule Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element No. Completion Scheduled Actual CoD of % Charges Schedule in CoD of the the Element recoverable Months Element on Scheduled CoD of the Element Element 1 28 1-Feb-2018 1-Feb-2018 25% Element 2 38 1-Dec-2018 1-Dec-2018 75% Tariff Payable as follows: [Insert Name of the SPV] 217 ……2026Transmission Service Agreement Transmission Charges for Element 1 Transmission Charges for Element 2 1-Feb-18 to 140 X 25% X 5.65 -- 0.00 31-Mar-18 ((28+31)/365) 1-Apr-18 to 140 X 25% X 23.39 -- 0.00 30-Nov-18 (244/365) 1-Dec-18 to 140 X 100% X (121/365) 46.41 31-Mar-19 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (244/365) 93.59 (1-Apr to 30- Nov) Illustration-2: In case of extension of Scheduled COD as per Article 4.4.1 & 4.4.2 of this Agreement Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element No. Completion Scheduled Actual CoD of % Charges Schedule in CoD of the the Element recoverable Months Element on Scheduled CoD of the Element Element 1 20 1-Feb-2018 1-Jul-2018 25% Element 2 28 1-Oct-2018 1-Dec-2018 75% Tariff Payable as follows: Transmission Charges for Element 1 Transmission Charges for Element 2 1-Feb-18 to -- 0.00 -- 0.00 31-Mar-18 1-Apr-18 to -- 0.00 -- 0.00 30-Jun-18 [Insert Name of the SPV] 218 ……2026Transmission Service Agreement 1-Jul-18 to 140 X 25% X 14.67 -- 0.00 30-Nov-18 (153/365) 1-Dec-18 to 140 X 100% X (121/365) 46.41 31-Mar-19 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (244/365) 93.59 (1-Apr to 30- Nov) Illustration-3: In case of delay in achieving COD of Project & all individual Elements (COD of the Project achieved in Contract Year 1) Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element No. Completion Scheduled Actual CoD of % Charges Schedule in CoD of the the Element recoverable Months Element on Scheduled CoD of the Element Element 1 20 1-Feb-2018 1-Dec-2018 25% Element 2 28 1-Oct-2018 1-Dec-2018 75% Tariff Payable as follows: Transmission Charges for Element 1 Transmission Charges for Element 2 1-Feb-18 to -- 0.00 -- 0.00 31-Mar-18 1-Apr-18 to -- 0.00 -- 0.00 30-Sept-18 1-Oct-18 to -- 0.00 1-Oct-18 to -- 0.00 30-Nov-18 30-Nov-18 1-Dec-18 to 140 X 100% X (121/365) 46.41 31-Mar-19 [Insert Name of the SPV] 219 ……2026Transmission Service Agreement 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (244/365) 93.59 (1-Apr to 30- Nov) [Insert Name of the SPV] 220 ……2026Transmission Service Agreement Illustration-4: In case of delay in achieving COD of Project & all individual Elements (COD of the Project achieved in Contract Year other than Contact Year 1) Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element Completion Scheduled Actual CoD of % Charges No. Schedule in CoD of the the Element recoverable on Months Element Scheduled CoD of the Element Element 1 38 1-Oct-2019 1-May-2020 25% Element 2 38 1-Oct-2019 1-May-2020 75% Tariff Payment to be paid as: Transmission Charges for Element 1 Transmission Charges for Element 2 1-Oct-19 to -- 0.00 1-Oct-19 to -- 0.00 31-Mar-20 31-Mar-20 1-Apr-20 to - 0.00 1-Apr-20 to - 0.00 30-Apr-20 30-Apr-20 1-May-20 to 140 X 100% X (335/365) 128.49 31-Mar-21 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (30/ 365) 11.51 (1-Apr to 30- Apr) [Insert Name of the SPV] 221 ……2026Transmission Service Agreement Illustration5: In case of delay in achieving COD of Element but Project COD achieved on time Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element Completion Scheduled Actual CoD of % Charges No. Schedule in CoD of the the Element recoverable on Months Element Scheduled CoD of the Element Element 1 20 1-Feb-2018 1-Jul-2018 25% Element 2 30 1-Dec-2018 1-Dec-2018 75% Tariff Payable as follows: Transmission Charges for Element 1 Transmission Charges for Element 2 1-Feb-18 to -- 0.00 -- 0.00 31-Mar-18 1-Apr-18 to -- 0.00 -- 0.00 30-Jun-18 1-Jul-18 to 140 X 25% X 14.67 -- 0.00 30-Nov-18 (153/365) 1-Dec-18 to 140 X 100% X (121/365) 46.41 31-Mar-19 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (244/365) 93.59 (1-Apr to 30- Nov) [Insert Name of the SPV] 222 ……2026Transmission Service Agreement Illustration-6: In case of early commissioning of Project Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element Completion Scheduled Actual CoD of % Charges No. Schedule in CoD of the the Element recoverable on Months Element Scheduled CoD of the Element Element 1 38 1-Oct-2019 1-Jul-2019 25% Element 2 38 1-Oct-2019 1-Jul-2019 75% Tariff Payment to be paid as: Transmission Charges for Element 1 Transmission Charges for Element 2 1-July-19 to 140 X 100% X (274/365) 105.09 31-Mar-20 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (91/365) 34.91 (1-Apr to 30- Jun) [Insert Name of the SPV] 223 ……2026Transmission Service Agreement Illustration-7: In case of early commissioning of an element Quoted Transmission Charges: Rs. 140 Million Completion Schedule: Element Completion Scheduled Actual CoD of % Charges No. Schedule in CoD of the the Element recoverable on Months Element Scheduled CoD of the Element Element 1 38 1-Oct-2019 1-Apr-2019 25% Element 2 38 1-Jul-2019 1-Jul-2019 75% Tariff Payment to be paid as: Transmission Charges for Element 1 Transmission Charges for Element 2 1-Apr-2019 to 140 X 25% X 8.72 1-Apr-2019 to -- 0.00 30-Jun-19 (91/365) 30-Jun-19 1-July-19 to 140 X 100% X (274/ 365) 105.09 31-Mar-20 2 140 X 100% X 1 140 3 140 X 100% X 1 140 4 140 X 100% X 1 140 5 140 X 100% X 1 140 ……………. …………….. 36 140 X 100% X (91/365) 34.91 (1-Apr-30- Jun) The Transmission Charges shall be payable on monthly basis as computed above. 1.2 Computation of Monthly Transmission Charges The Monthly Transmission Charges for any month m in a Contract Year n shall be calculated as below: For AC System: [Insert Name of the SPV] 224 ……2026Transmission Service Agreement a. If Actual Transmission System Availability for the month m of contract year n is greater than or equal to 98% and less than or equal to 98.5%; Monthly Transmission Charges MTC(m) = Tmn *1 b. If Actual Transmission System Availability for the month m of contract year n exceeds 98.5% and less than or equal to 99.75%; Monthly Transmission Charges MTC(m) = Tmn * (AA/ 98.5%) c. If Actual Transmission System Availability for the month m of contract year n is greater than 99.75%; Monthly Transmission Charges MTC(m) = Tmn * (99.75% / 98.5%) d. If Actual Transmission System Availability for the month m of contract year n is less than 98% and greater than or equal to 95.00%; Monthly Transmission Charges MTC(m) = Tmn * (AA/ 98%) e. If Actual Transmission System Availability for the month m of contract year falls below 95%; Monthly Transmission Charges MTC(m) = Tmn * (AA/ 98%) - 0.02 * (Tmn * (AA/ 95%) For DC System: a. If Actual Transmission System Availability for the month m of contract year n is greater than or equal to 95% and less than or equal to 96%; Monthly Transmission Charges MTC(m) = Tmn *1 b. If Actual Transmission System Availability for the month m of contract year n exceeds 96% and less than or equal to 99.75%; Monthly Transmission Charges MTC(m) = Tmn * (AA/ 96%) c. If Actual Transmission System Availability for the month m of contract year n is greater than 99.75%; Monthly Transmission Charges MTC(m) = Tmn * (99.75% / 96%) d. If Actual Transmission System Availability for the month m of contract year n is less than 95% and greater than or equal to 92.00%; Monthly Transmission Charges MTC(m) = Tmn * (AA/ 95%) e. If Actual Transmission System Availability for the month m of contract year falls below 92%; Monthly Transmission Charges MTC(m) = Tmn * (AA/ 95%) - 0.02 * (Tmn * (AA/ 92%) [Insert Name of the SPV] 225 ……2026Transmission Service Agreement where:  AA is the actual Availability, as certified by RPC, as per procedure provided in Schedule 6.  m is the month in Contract Year ‘n’  Tmn= Transmission Charges for the month ‘m’ in Contract Year ‘n’ = (=Transmission Charge/ no. of days in the Year n)* no. of days in month m. Provided, no Transmission Charges shall be paid during the period for which the RLDC has not allowed the operation of the Element/Project due to the failure of the TSP to operate it as per the provisions of the Grid Code. 1.3 RLDC Fee & Charges The payment of RLDC fee & charges, in accordance with relevant regulations of CERC, shall be the responsibility of the TSP. [Insert Name of the SPV] 226 ……2026Transmission Service Agreement Schedule: 5 Quoted Transmission Charges [Quoted Transmission Charges from Annexure - 21 of the RFP of the Selected Bidder to be inserted here] [To be incorporated from the Bid of the Selected Bidder submitted during the e- reverse auction after its selection] Quoted Transmission Charges: Rs. ……………… Million Proportionate Transmission Charges payable for each Element of the Project: Element(s) % of Quoted which are pre- Transmission required for Charges declaring the Sl. Name of the Transmission recoverable on commercial No. Element Scheduled COD operation of the Element of (COD) of the the Project respective Element 1. Establishment of 4x1500 MVA, 765/400 kV Pendurthi (Vizag) GIS Element at Sl. substation with 1x330 MVAr (765 No. 2, 3, 4, 5, kV) bus reactor with space provision 6 , 7 & 8 for establishment of 220 kV switchyard 2. ± 300 MVAr STATCOM with 2x125 MVAr MSC at Pendurthi (Vizag) Element at Sl. GIS with control switching No. 1, 3, 4, 5, 100 arrangement for proposed 1x330 6, 7 & 8 MVAr bus reactor 3. Pendurthi (Vizag) – Srikakulam 765 Element at Sl. kV D/c line with 330 MVAr SLR No. 1, 2, 4, 5, (convertible) at Srikakulam end on 6, 7 & 8 both circuits 4. LILO of Kalpakka – Maradam 400 Element at Sl. kV (quad) D/c line at Pendurthi No. 1, 2, 3, 5, 6, 7 & 8 [Insert Name of the SPV] 227 ……2026Transmission Service Agreement Element(s) % of Quoted which are pre- Transmission required for Charges declaring the Sl. Name of the Transmission recoverable on commercial No. Element Scheduled COD operation of the Element of (COD) of the the Project respective Element 5. Establishment of 3x1500 MVA, 765/400 kV Khammam-II substation Element at Sl. with 1x330 MVAr (765 kV) bus No. 1, 2, 3, 4, reactor with space provision for 6, 7 & 8 establishment of 220 kV switchyard 6. Khammam-II – Warangal New 765 Element at Sl. kV D/c line No. 1, 2, 3, 4, 5 ,7 & 8 7. Khammam-II – Pendurthi (Vizag) Element at Sl. 765 kV D/c line with 330 MVAr SLR No. 1, 2, 3, 4, (convertible) at both ends on both 5, 6 & 8 circuits 8. Khammam-II – Khammam Element at Sl. (existing) 400 kV (quad) D/c line No. 1, 2, 3, 4, 5, 6 & 7 [Insert Name of the SPV] 228 ……2026Transmission Service Agreement Schedule: 6 Appendix IV of the Central Electricity Regulatory Commission (Terms and Conditions of Tariff) Regulations 2024 Procedure for Calculation of Transmission System Availability Factor for a Month 1. Transmission system availability factor for nth calendar month (“TAFPn”) shall be calculated by the respective transmission licensee, verified by the concerned Regional Load Dispatch Centre (RLDC) and certified by the Member-Secretary, Regional Power Committee of the region concerned, separately for each AC and HVDC transmission system and grouped according to sharing of transmission charges. In the case of the AC system, transmission System Availability shall be calculated separately for each Regional Transmission System and inter-regional transmission system. In the case of the HVDC system, transmission System Availability shall be calculated on a consolidated basis for all inter-state HVDC systems. 2. Transmission system availability factor for nth calendar month (“TAFPn”) shall be calculated by considering the following: i) AC transmission lines: Each circuit of AC transmission line shall be considered as one element; ii) Inter-Connecting Transformers (ICTs): Each ICT bank (three single-phase transformers together) shall form one element; iii) Static VAR Compensator (SVC): SVC, along with SVC transformer, shall form one element; iv) Bus Reactors or Switchable line reactors: Each Bus Reactors or Switchable line reactors shall be considered as one element; v) HVDC Bi-pole links: Each pole of the HVDC link, along with associated equipment at both ends, shall be considered as one element; vi) HVDC back-to-back station: Each block of the HVDC back-to-back station shall be considered as one element. If the associated AC line (necessary for the transfer of inter-regional power through the HVDC back-to-back station) is not available, the HVDC back-to-back station block shall also be considered unavailable; [Insert Name of the SPV] 229 ……2026Transmission Service Agreement vii) Static Synchronous Compensation (“STATCOM”): Each STATCOM shall be considered as a separate element. 3. The Availability of the AC and HVDC portion of the Transmission system shall be calculated by considering each category of transmission elements as under: [Insert Name of the SPV] 230 ……2026Transmission Service Agreement 4. The availability for each category of transmission elements shall be calculated based on the weightage factor, total hours under consideration and non- available hours for each element of that category. The formulae for calculation of the Availability of each category of the transmission elements are as per Appendix-V. The weightage factor for each category of transmission elements shall be considered as under: (a) For each circuit of the AC line – The number of sub-conductors in the line multiplied by ckt-km; (b) For each HVDC pole- The rated MW capacity x ckt-km; (c) For each ICT bank – The rated MVA capacity; (d) For SVC- The rated MVAR capacity (inductive and capacitive); (e) For Bus Reactor/switchable line reactors – The rated MVAR capacity; (f) For HVDC back-to-back stations connecting two Regional grids- Rated MW capacity of each block; and (g) For STATCOM – Total rated MVAR Capacity. 5. The transmission elements under outage due to the following reasons shall be deemed to be available: i. Shut down availed for maintenance of another transmission scheme or construction of new element or renovation/upgradation/additional capitalization in an existing system approved by the Commission. If the other transmission scheme belongs to the transmission licensee, the Member Secretary, RPC may restrict the deemed availability period to that considered reasonable by him for the work involved. In case of a dispute regarding deemed availability, the matter may be referred to the Chairperson, CEA, within 30 days. ii. Switching off of a transmission line to restrict over-voltage and manual tripping of switched reactors as per the directions of the concerned RLDC. iii. Shut down of a transmission line due to the Project(s) of NHAI, Railways and Border Road Organization, including for shifting or modification of such transmission line or any other infrastructure project approved by Ministry of Power. Member Secretary, RPC may restrict the deemed availability period to that considered reasonable by him for the work involved; Provided that apart from the deemed availability, any [Insert Name of the SPV] 231 ……2026Transmission Service Agreement other costs involved in the process of such shutdown of transmission line shall not be borne by the DICs. Provided that such deemed availability shall be considered only for the period for which DICs are not affected by the shutdown of such transmission line. 6. For the following contingencies, the outage period of transmission elements, as certified by the Member Secretary, RPC, shall be excluded from the total time of the element under the period of consideration for the following contingencies: i) Outage of elements due to force majeure events beyond the control of the transmission licensee. However, whether the same outage is due to force majeure (not design failure) will be verified by the Member Secretary, RPC. A reasonable restoration time for the element shall be considered by the Member Secretary, RPC, and any additional time taken by the transmission licensee for restoration of the element beyond the reasonable time shall be treated as outage time attributable to the transmission licensee. Member Secretary, RPC may consult the transmission licensee or any expert for estimation of reasonable restoration time. Circuits restored through ERS (Emergency Restoration System) shall be considered as available; ii) Outage caused by grid incident/disturbance not attributable to the transmission licensee, e.g. faults in a substation or bays owned by another agency causing an outage of the transmission licensee’s elements, and tripping of lines, ICTs, HVDC, etc., due to grid disturbance. However, if the element is not restored on receipt of direction from RLDC while normalizing the system following grid incident/disturbance within reasonable time, the element will be considered not available for the period of outage after issuance of RLDC’s direction for restoration; iii) The outage period which can be excluded for the purpose of sub-clause (i) and (ii) of this clause shall be declared as under: a. Maximum up to one month by the Member Secretary, RPC; b. Beyond one month and up to three months after the decision at RPC; c. Beyond three months by the Commission for which the transmission license shall approach the Commission along with reasons and steps taken to mitigate the outage and restoration timeline. [Insert Name of the SPV] 232 ……2026Transmission Service Agreement 7. Time frame for certification of transmission system availability: (1) The following schedule shall be followed for certification of availability by the Member Secretary of the concerned RPC: • Submission of outage data along with documentary proof (if any) and TAFPn calculation by Transmission Licensees to RLDC/ constituents – By the 5th of the following month; • Review of the outage data by RLDC / constituents and forward the same to respective RPC – by 20th of the month; • Issue of availability certificate by respective RPC – by the 3rd of the next month. [Insert Name of the SPV] 233 ……2026Transmission Service Agreement [Insert Name of the SPV] 234 ……2026Transmission Service Agreement [Insert Name of the SPV] 235 ……2026Transmission Service Agreement Schedule: 7 Entire Bid (both financial bid and technical bid) of the Selected Bidder to be attached here [Insert Name of the SPV] 236 ……2026Transmission Service Agreement Schedule: 8 Contract Performance Guarantee (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign entities submitting Bids are required to follow the applicable law in their country.) In consideration of the ……………………..[Insert name of the SPV or Selected Bidder on behalf of the TSP, or Lead Member in case of the Consortium, with address] agreeing to undertake the obligations under the Transmission Service Agreement dated ……….and the other RFP Project Documents and the Nodal Agency and the ……………………..[Insert the name of the BPC], agreeing to execute the RFP Project Documents with the Selected Bidder, regarding setting up the Project, the ………………………………. [Insert name and address of the bank issuing the guarantee and address of the head office] (hereinafter referred to as “Guarantor Bank”) hereby agrees unequivocally, irrevocably and unconditionally to pay to …………… (being the Nodal Agency) at ……………………[Insert the Place from the address of the Nodal Agency indicated in the TSA] forthwith on demand in writing from the Nodal Agency or any Officer authorized by it in this behalf, any amount up to and not exceeding Rupees ………………………….. Crores (Rs. ……….) only [Insert the amount of the bank guarantee] on behalf of M/s. …………………………………. [Insert name of the Selected Bidder or SPV]. This guarantee shall be valid and binding on the Guarantor Bank up to and including ……………………….and shall not be terminable by notice or any change in the constitution of the Bank or the term of the Transmission Service Agreement or by any other reasons whatsoever and our liability hereunder shall not be impaired or discharged by any extension of time or variations or alternations made, given, or agreed with or without our knowledge or consent, by or between parties to the respective agreement. Our liability under this Guarantee is restricted to Rs. ………………….. Crores (Rs. ……………………………..) only. Our Guarantee shall remain in force until ……………………………………….. [Insert the date of validity of the Guarantee as per Article 3.1.2 of this Agreement]. The Nodal Agency, shall be entitled to invoke this Guarantee up to three hundred sixty five (365) days of the last date of the validity of this Guarantee. [Insert Name of the SPV] 237 ……2026Transmission Service Agreement The Guarantor Bank hereby expressly agrees that it shall not require any proof in addition to the written demand from …………… (in its roles as the Nodal Agency), made in any format, raised at the above mentioned address of the Guarantor Bank, in order to make the said payment to Nodal Agency. The Guarantor Bank shall make payment hereunder on first demand without restriction or conditions and notwithstanding any objection by ...................................... [Insert name of the Selected Bidder], ……………………….. [Insert name of the TSP] and / or any other person. The Guarantor Bank shall not require Nodal Agency to justify the invocation of this BANK GUARANTEE, nor shall the Guarantor Bank have any recourse against Nodal Agency in respect of any payment made hereunder. THIS BANK GUARANTEE shall be interpreted in accordance with the laws of India. The Guarantor Bank represents that this BANK GUARANTEE has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Guarantor Bank in the manner provided herein. THIS BANK GUARANTEE shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Guarantor Bank. THIS BANK GUARANTEE shall be a primary obligation of the Guarantor Bank and accordingly Nodal Agency shall not be obliged before enforcing this BANK GUARANTEE to take any action in any court or arbitral proceedings against …………………… [Insert name of the SPV] or the Selected Bidder, as the case may be, to make any claim against or any demand on …………………… [Insert name of the SPV] or the Selected Bidder, as the case may be, or to give any notice to …………………… [Insert name of the SPV] or the Selected Bidder, as the case may be, or to enforce any security held by the Nodal Agency or to exercise, levy or enforce any distress, diligence or other process against …………………… [Insert name of the SPV] or the Selected Bidder, as the case may be. The Guarantor Bank acknowledges that this BANK GUARANTEE is not personal to Nodal Agency and may be assigned, in whole or in part, (whether absolutely or by way of security) by Nodal Agency to any entity to whom the Nodal Agency is entitled to assign its rights and obligations under the Transmission Service Agreement. The Guarantor Bank hereby agrees and acknowledges that Nodal Agency shall have a right to invoke this Bank Guarantee either in part or in full, as it may deem fit. [Insert Name of the SPV] 238 ……2026Transmission Service Agreement Notwithstanding anything contained hereinabove, our liability under this Guarantee is restricted to Rs. ………………….. Crores (Rs. …………………..) only and it shall remain in force until ………………………[Date to be inserted on the basis of Article 3.1.2of the Transmission Service Agreement], with an additional claim period of three hundred sixty five (365) days thereafter. This BANK GUARANTEE shall be extended from time to time for such period, as may be desired by …………………………………….. [Insert name of the Selected Bidder or Lead Member in case of the Consortium or SPV]. We are liable to pay the guaranteed amount or any part thereof under this Bank Guarantee only if Nodal Agency serves upon us a written claim or demand. In witness where of: Signature .............................................. Name: ................................................... Power of attorney No.: ……………………………… For: ………………………………….. [Insert Name of the Bank] Banker's Seal and Full Address, including mailing address of the Head Office [Insert Name of the SPV] 239 ……2026Transmission Service Agreement SCHEDULE: 8A (ISB for CPG) FORMAT FOR SURETY INSURANCE CONTRACT (To be on non-judicial stamp paper of appropriate value as per Stamp Act relevant to place of execution. Foreign entities submitting Bids are required to follow the applicable law of India) In consideration of the .................................. [Insert name of the SPV or Selected Bidder on behalf of SPV or Lead Member in case of the Consortium, with address] (hereinafter referred to as the 'Principal Debtor' for the purposes of this Surety Insurance Contract as provided in Section 126 of the Indian Contract Act, 1872) having been selected to undertake the Transmission Project on the terms and conditions contained in the Transmission Service Agreement dated ..............................I to be executed as per the Model Transmission Service Agreement provided along with the Request for Proposal ('RFP') and other RFP Project Documents, subject to the condition of providing a Performance Bank Guarantee or a Surety Insurance Contract guaranteeing/insuring the due performance of the obligations under the Transmission Service Agreement, to the Central Transmission Utility of India Limited ('CTUIL') [herein after referred to as the Nodal Agency], the [Insert name and address of the Insurance Company issuing the Surety Insurance Contract and address of the head office] (hereinafter referred to as "Surety") hereby agrees unequivocally, irrevocably, absolutely and unconditionally, without demur, to pay to the Nodal Agency at [Insert Place and Address of the Nodal Agency indicated in Transmission Service Agreement, or to the designated Bank Account of the Nodal Agency, namely........] forthwith on demand in writing from the Nodal Agency, or any Officer authorized by it in this behalf, intimated to the Surety at the address mentioned above, any amount as may be decided by the Nodal Agency not exceeding Rupees .................................Crores (Rs...................) only [Insert the amount of the Surety Insurance Contract] The Surety hereby acknowledges, accepts and confirms that the Surety has received from the Principal Debtor, by way of premium the entire consideration for the Surety to execute, in favour of the Nodal Agency, this Surety Insurance Contract, as extended by the Surety from time to time and assuming the obligation to pay to the Nodal Agency the amount in terms hereof, without any requirement for payment of any other consideration to the Surety by the Principal Debtor, or otherwise. This Surety Insurance Contract shall be valid and binding on the Surety, as the principal obligation of the Surety to pay on demand by the Nodal Agency, and shall not be terminable by notice or any change in the constitution of the Surety or the term of the Transmission Service Agreement or by any other reasons whatsoever and the liability hereunder of the Surety shall not be impaired or discharged by any extension of time or variations or alternations made, given, or agreed (with or without the knowledge or consent of the Surety) by or between the Principal Debtor and the Nodal Agency. [Insert Name of the SPV] 240 ……2026Transmission Service Agreement The liability of the Surety under this Surety Insurance Contract is restricted to Rupees ................ Crores (Rs ................ ) only. The Surety Insurance Contract shall remain in force until [Insert the date of validity of the Surety Insurance Contract]. The Nodal Agency shall be entitled to invoke this Surety Insurance Contract up to three hundred sixty five (365) days after the last date of the validity of this Surety Insurance Contract. The Surety hereby expressly agrees that it shall not require any proof except for the written demand from the Nodal Agency, containing the statement that the contractor has failed to meet its contractual obligations raised at the above mentioned address of the Surety (address of Surety office should be a place in NCR only) and the Surety shall pay the amount without reference to the Principal Debtor. Any such demand made by the Nodal Agency on the Surety shall be conclusive and binding not withstanding any difference between the Nodal Agency and the Principal Debtor or any dispute pending before any Court, Tribunal, Arbitrator or any other authority. The Surety undertakes not to revoke this guarantee during its currency without previous consent of the Nodal Agency and further agrees that the Surety Insurance Contract herein contained shall continue to be enforceable till the Nodal Agency discharges this contract or till the expiry of tenor(including Claim period) whichever is earlier. The Surety shall make payment hereunder within two (02) working days on first demand without restriction or conditions and notwithstanding any objection by the Principal Debtor, namely, ......... [Insert name of SPV], or ......... [Insert name of the Selected Bidder], or ............. [Insert name of the TSP] and/or any other person. The Surety shall not require the Nodal Agency to justify the invocation of this Surety Insurance Contract, nor shall the Surety have any recourse against the Nodal Agency in respect of any payment made hereunder. This SURETY INSURANCE CONTRACT shall be interpreted in accordance with the laws of India. This SURETY INSURANCE CONTRACT is being executed by the Surety in terms of the IRDAI (Surety Insurance Contract) Guidelines, 2022 and the Surety hereby acknowledges, accepts and confirms that this Surety Insurance Contract shall be a Contract of Guarantee as provided under Section 126 of the Indian Contract Act, 1872 and further shall be covered by Section 14(3)(b) of the Insolvency and Bankruptcy Code, 2016 (as amended) shall be enforceable as such. The Surety represents that this Surety Insurance Contract has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Surety in the manner provided herein. This SURETY INSURANCE CONTRACT shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Surety. In order to give effect to this surety Bond, the Nodal Agency shall be entitled to act as if the surety insurer were the principal debtor and any change in the constitution of the contractor and/or the surety insurer, whether by their absorption with any other body [Insert Name of the SPV] 241 ……2026Transmission Service Agreement or corporation or otherwise, shall not in any way or manner affect the liability or obligation of the surety insurer under this surety Bond. This SURETY INSURANCE CONTRACT shall be a primary obligation of the Surety as a Principal to pay on demand by the Nodal Agency and the Nodal Agency shall not be obliged before enforcing this Surety Insurance Contract to take any action in any court or arbitral proceedings against the Principal Debtor, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be, to make any claim against or any demand on the Principal Debtor, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or.................................. [Insert name of the TSP] and/or any other person, as the case may be, or to give any notice to Principal Debtor, namely.................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or.................................. [Insert name of the TSP] and/or any other person, as the case may be, or to enforce any security held by the Nodal Agency or to exercise, levy or enforce any distress, diligence or other process against the Principal Debtor, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be. The Surety acknowledges that this Surety Insurance Contract is not personal to the Nodal Agency and may be assigned, in whole or in part, (whether absolutely or by way of security) by Nodal Agency to any entity to whom the Nodal Agency is entitled to assign its rights and obligations under the Transmission Service Agreement Provided that any such assignment shall be in compliance with the relevant provisions of the Insurance Act 1938 The Surety hereby agrees and acknowledges that the Nodal Agency shall have a right to invoke this Surety Insurance Contract either in part or in full, as it may deem fit. In case of invocation of this Surety Insurance Contract in part, besides making payment for the part of Surety Insurance Contract invoked, surety at the request of nodal agency shall amend the value of Surety Insurance Contract to the extent of balance amount. The Surety undertakes not to revoke this Surety Contract during its currency, except with the previous express consent of the Nodal Agency in writing and declares and warrants that it has the power to issue this Surety Contract and the undersigned has full powers to do so on behalf of the Surety In witness where of: Signature............................................... Name: ................................................... Power of attorney No/ Employee No. as applicable. ..................................: [Insert Name of the SPV] 242 ……2026Transmission Service Agreement For: .................................. [Insert Name of the Surety-Insurance Companyl Banker's Seal and Full Address, including mailing address of the Head Office Notes: 1. The Stamp Paper should be in the name of the Executing Insurance Company. [Insert Name of the SPV] 243 ……2026Transmission Service Agreement SCHEDULE: 8B (POI for CPG) Format for Issuance of Payment on Order Instrument Dear Sir, 1. Indian Renewable Energy Development Agency Limited ('IREDA")/PFC/REC has sanctioned a non-fund-based limit loan of Rs. (Rupees............................................. Only) to M/s. .................................. [Insert name of SPV or selected Bidder] under the Loan Agreement executed on ......................... to execute Transmission System Projects. 2. In consideration of the ..................................[Insert name of the SPV or Selected Bidder on behalf of SPV or Lead Member in case of the Consortium, with address] for the purposes of this Payment on Order Instrument ("POI") having been selected to undertake the Transmission Project on the terms and conditions contained in the Transmission Service Agreement dated ..............................I to be executed as per the draft of the Model Transmission Service Agreement provided along with the Request for Proposal (,,RFP") and other RFP Project Documents, subject to the condition of providing a POI guaranteeing the due performance of the obligations under the Transmission Service Agreement to the Nodal Agency/Central Transmission Utility of India Limited (,,CTUIL"), the.................................[Insert name and address of the non- banking financial institutions(IREDA/PFC/REC) issuing the POI and address of the head office] (hereinafter referred to as "Guarantor") hereby agrees unequivocally, irrevocably, absolutely and unconditionally, without demur, to pay to the Nodal Agency at ............................ [Insert Place and Address of the Nodal Agency indicated in Transmission Service Agreement, or to the designated Bank Account of the Nodal Agency, namely ……………….. ] forthwith on demand in writing from the Nodal Agency, or any Officer authorized by it in this behalf, intimated to the Guarantor at the address mentioned above, any amount as may be decided by the Nodal Agency not exceeding Rupees .......................................... Crores (Rs ..................................) only [Insert the amount of Payment on Order Instrument] 3. At the request of ......................... and on behalf of M/s. ............................................., [Insert name of SPV or selected Bidder] this Payment on Order Instrument (POI) for an amount of Rs. ............................. (Rupees .............................) is being issued with IREDA/PFC/REC assuming the obligations to remit such amount to CTUIL from the sanctioned loan. 4. This Payment on Order Instrument comes into force immediately and IREDA/PFC/REC confirms that it has sufficient amount out of the sanctioned loan and shall maintain the required amount to pay under this Payment on Order Instrument, during the validity and claim period of this Payment on Order Instrument. 5. This POI has been issued by IREDA/PFC/REC utilizing the credit limit of M/s......................................................[Insert name of SPV or selected Bidder] IREDA/PFC/REC confirms that its liability to pay under this Payment on Order Instrument shall be primary and independent of whether at the time of invocation of [Insert Name of the SPV] 244 ……2026Transmission Service Agreement Payment on Order Instrument, the sanctioned funds are available or not and notwithstanding, the status of M/s [Insert name of SPV or selected Bidder] at the relevant time and to whether IREDA/PFC/REC is able to recover the amount advanced by it to the said developer. 6. IREDA/PFC/REC and M/s.[Insert name of SPV or selected Bidder] hereby acknowledges, accepts and confirms that this Payment on Order Instrument shall be a Contract of Guarantee as provided under Section 126 of the Indian Contract Act, 1872 and further shall be covered by Section 14(3)(b) of the Insolvency and Bankruptcy Code, 2016 (as amended) shall be enforceable as such. 7. IREDA/PFC/REC liability under this POI is restricted to Rupees Crores (Rs...........................) only. This POI shall remain in force until............... [Insert the date of validity of the POI]. The Nodal Agency shall be entitled to invoke this POI up to three hundred sixty-five (365) days after the last date of the validity of this POI. This POI shall be extended from time to time for such period, as may be desired by the TSP. 8. The Guarantor hereby expressly agrees that it shall not require any proof except for the written demand from the Nodal Agency, raised at the above mentioned address of the Guarantor (address of Guarantor office should be in NCR only) and the Guarantor shall pay the amount to the Nodal Agency without reference to the TSP. 9. Any such demand made by the Nodal Agency on the Guarantor shall be conclusive and binding not withstanding any difference between the Nodal Agency and the TSP or any dispute pending before any Court, Tribunal, Arbitrator or any other authority. The Guarantor undertakes not to revoke this guarantee during its currency without previous consent of the Nodal Agency and further agrees that the POI herein contained shall continue to be enforceable till the Nodal Agency discharges this contract or till the expiry of tenure or (including Claim period) whichever is earlier. 10. The Guarantor shall make payment hereunder within two (02) working days on first demand without restriction or conditions and notwithstanding any objection or disputes raised by the TSP, namely, .................................. [Insert name of SPV], or [Insert name of the Selected Bidder], or.................................. [Insert name of the TSP] and/or any other person. The Guarantor shall not require the Nodal Agency to justify the invocation of this POI, nor shall the Guarantor have any recourse against the Nodal Agency in respect of any payment made hereunder. 11. This POI shall be interpreted in accordance with the laws of India. 12. The Guarantor represents that this POI Contract has been established in such form and with such content that it is fully enforceable in accordance with its terms as against the Guarantor in the manner provided herein. 13. This POI shall not be affected in any manner by reason of merger, amalgamation, restructuring, liquidation, winding up, dissolution or any other change in the constitution of the Guarantor. [Insert Name of the SPV] 245 ……2026Transmission Service Agreement 14. This POI Contract shall be a primary obligation of the Guarantor as a Principal to pay on demand by the Nodal Agency and the Nodal Agency shall not be obliged before enforcing this POI Contract to take any action in any court or arbitral proceedings against the TSP, namely, .................................. [Insert name of SPV], or.................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be to make any claim against or any demand on the TSP, namely, .................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be, or to give any notice to TSP, namely.................................. [Insert name of SPV], or .................................. [Insert name of the Selected Bidder], or .................................. [Insert name of the TSP] and/or any other person, as the case may be, or to enforce any security held by the Nodal Agency or to exercise, levy or enforce any distress, diligence or other process against the TSP, namely, .................. [Insert name of SPV], or.[Insert name of the Selected Bidder], or ............. [Insert name of the TSP] and/or any other person, as the case may be. 15. The Guarantor acknowledges that this POI Contract is not personal to the Nodal Agency and may be assigned, in whole or in part, (whether absolutely or by way of security) by Nodal Agency to any entity to whom the Nodal Agency is entitled to assign its rights and obligations under the Transmission Service Agreement. 16. The Guarantor hereby agrees and acknowledges that the Nodal Agency shall have a right to invoke this POI Contract either in part or in full, as it may deem fit. In case of invocation of this POI Contract in part, besides making payment for the part of POI Contract invoked, Guarantor at the request of Nodal Agency shall amend the value of POI Contract to the extent of balance amount. IN WITNESS WHERE OF the non- banking financial institutions through its authorized officer, has set its hand and stamp on this....... day of........at......... Signature .............................................. Name: .................................. Power of attorney No.: .................................. For: .................................. [Insert Name of the non- banking financial institutions Company] Seal and Full Address, including mailing address of the Head Office [Insert Name of the SPV] 246 ……2026Transmission Service Agreement Schedule: 9 Methodology for determining the Relief Under Force Majeure Event & Change in Law during Construction Period The relief in the form of revision in tariff due to Force Majeure Event leading to extension of Scheduled COD for a period beyond one hundred eighty (180) days and/ or Change in Law during the construction period shall be as under: ΔT = [(P x d)]÷[1-(1+ d)^(-n)] Where, ΔT = Change in Transmission Charges for each year P = Sum of cumulative increase or decrease in the cost of the Project due to Change in Law and interest cost during construction corresponding to the period exceeding one hundred eighty (180) due to Force Majeure Event leading to extension of Scheduled COD for a period beyond one hundred eighty (180) days n = number of years over which the Transmission Charges has to be paid d = Discount rate as notified by the CERC, applicable on the Bid Deadline The increase in Transmission Charges as stated above shall be applicable only if the value of increase in Transmission Charges as calculated above exceeds 0.30% (zero point three percent) of the quoted Transmission Charges of the TSP. [Insert Name of the SPV] 247 ……2026SHARE PURCHASE AGREEMENT BETWEEN REC POWER DEVELOPMENT AND CONSULTANCY LIMITED AND ……………. (Name of SPV) AND [Insert name of the Selected Bidder] Dated: [insert date]Share Purchase Agreement SHARE PURCHASE AGREEMENT This SHARE PURCHASE AGREEMENT (‘Agreement’) made this day of [Insert Date of the Agreement] 2026 at New Delhi by and between: REC POWER DEVELOPMENT AND CONSULTANCY LIMITED, a company incorporated under the Companies Act, 1956, having its registered office at Core 4, SCOPE Complex, 7, Lodhi Road, New Delhi 110 003, India (hereinafter referred to as “REC PDCL”, which expression shall, unless it be repugnant to the context or meaning thereof, be deemed to mean and include its successors and permitted assigns) of the FIRST PART; AND …………….. (Name of SPV), a company incorporated under the Companies Act, 2013, having its registered office at Core 4, SCOPE Complex, 7, Lodhi Road, New Delhi 110 003, India (hereinafter referred to as “Company” which expression shall, unless repugnant to the context, mean and include its successors in interest) of the SECOND PART; and AND [Insert Name of the Selected Bidder] a company incorporated under the Companies Act, 1956 having its registered office at [Insert the registered office address of the Selected Bidder] (hereinafter referred to as “Selected Bidder” which expression shall, unless repugnant to the context or meaning thereof, be deemed to mean and include its successors and permitted assigns) of the THIRD PART. Note: [In case the Selected Bidder is a Bidding Consortium, the above immediate paragraph shall be replaced by the following: ……………………………. [Insert Name of the Lead Member], a company incorporated under the Companies Act, 1956 and having its registered office at ……………………. [Insert the registered office address of Lead Member] AND ……………………………. [Insert Name of the Member], a company incorporated under the Companies Act, 1956 and having its registered office at ……………………. [Insert the registered office address of Member] (hereinafter individually referred to as “Partner 1” and “Partner 2” respectively and collectively referred to as “Selected Bidder” which expression shall, unless repugnant to the context or meaning thereof, be deemed to mean and include its successors and permitted assigns) of the THIRD PART 1 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement WHEREAS: A. Ministry of Power, Government of India vide its Gazette Notification No. 5827 [F. No. 15/3/2018-Trans-Part (4)] dated 26.12.2025 has appointed REC Power Development and Consultancy Limited to be the Bid Process Coordinator (BPC) for the purpose of selection of Bidder as Transmission Service Provider (TSP) to establish transmission system for “Transmission System for Proposed Green Hydrogen /Green Ammonia projects in Vizag area, Andhra Pradesh (Phase-I)” through tariff based competitive bidding process. B. In accordance with the Bidding Guidelines, the BPC had initiated a competitive bidding process through issue of RFP for selecting a Successful Bidder to build, own, operate and transfer the Project comprising of the Elements mentioned in Schedule 2 of the TSA. BPC had initiated this process in accordance with and on the terms and conditions mentioned in the RFP Project Documents (as defined hereinafter). C. BPC has incorporated the Company and has undertaken the preliminary studies, obtained certain approvals, etc. regarding the Project on behalf of the Company D. REC PDCL along with the Nominees hold one hundred per cent (100%) of the total issued and paid-up equity share capital of the Company. E. Pursuant to the said Bid Process, [Insert Name of the Selected Bidder] has been identified as the Selected Bidder vide Letter of Intent dated [Insert Date of the Letter of Intent] issuedb y the BPC in favour of the Selected Bidder. F. As envisaged in the RFP, the Shares Seller (as defined hereinafter) has agreed to sell the Sale Shares (as defined hereinafter) to the Selected Bidder and the Selected Bidder has agreed to purchase the Sale Shares from the Shares Seller, subject to and on the terms and conditions set forth in this Agreement. NOW THEREFORE, IN CONSIDERATION OF THE MUTUAL COVENANTS AND AGREEMENTS SET FORTH IN THIS AGREEMENT AND FOR OTHER GOOD AND VALUABLE CONSIDERATION, THE PARTIES HEREBY AGREE AS FOLLOWS: 1. DEFINITIONS 1.1 Capitalised terms in this Agreement, unless defined in this Agreement shall, in so far as the context admits, have the same meaning in this Agreement as has been ascribed to them in the TSA. 1.2 Additionally, the following terms shall have the meaning hereinafter respectively assigned to them herein below: 2 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement (i) “Acquisition Price” shall mean INR (Rupees only) [Insert the value of the Acquisition Price, both in figures and in words respectively], which is the aggregate consideration payable by the Selected Bidder towards purchase of the Sale Shares at par and for taking over of all assets and liabilities of the Company as on the Closing Date subject to adjustment as per the audited accounts of the Company as on the Closing Date; (ii) “Agreement” or “the Agreement” or “this Agreement” shall mean this Share Purchase Agreement and shall include the recitals and/or annexures attached hereto, and the contracts, certificates, disclosures and other documents to be executed and delivered pursuant hereto, if any, and any amendments made to this Agreement by the Parties in writing; (iii) “Bid Process” shall mean the competitive bidding process initiated by the BPC, by issuance of RFP for selecting a Successful Bidder to build, own, operate and transfer the Project in accordance with and on the terms and conditions mentioned in the RFP Project Documents; (iv) “Board” shall mean the board of directors of the Company; (v) “Closing Date” shall mean a mutually agreed date between the Parties falling within the period as mentioned in clause 2.15.2 of RFP or on failure of such mutual agreement between the Parties shall be the date falling on the last date of such period; (vi) “Encumbrance” shall mean any mortgage, pledge, lien, charge, security assignment, hypothecation, trust, encumbrance or any other agreement having the effect of creating security interest; (vii) “Letter of Intent” shall have the meaning ascribed thereto under the Bid Documents; (viii) “Nominees” shall mean the Persons, who are named in Annexure A of this Agreement, holding the Sale Shares as nominees of REC PDCL; 3 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement (ix) “Party” shall mean REC PDCL, Company and the Selected Bidder, referred to individually, and “Parties” shall mean REC PDCL, Company and the Selected Bidder collectively referred to, as relevant; (x) “Person” shall include an individual, an association, a corporation, a partnership, a joint venture, a trust, an unincorporated organisation, a joint stock company or other entity or organisation, including a government or political subdivision, or an agency or instrumentality thereof, and/or any other legal entity; (xi) “RFP Project Documents” shall mean the following documents, referred to collectively: a) Transmission Service Agreement; and b) this Agreement. (xii) “Representations and Warranties” shall mean the representations and warranties mentioned in Clause 4 hereto; (xiii) “RoC” shall mean the Registrar of Companies; (xiv) “Sale Shares” shall mean [Insert total number of shares of the Company] shares, representing one hundred percent (100%) of the total issued, subscribed and fully paid-up equity share capital of the Company held by the Shares Seller and Nominees as more particularly described in Annexure A attached hereto; (xv) “Shares” shall mean the fully paid-up equity shares of Company, of face value Rs. 10 each; (xvi) “Shares Seller” shall mean REC PDCL; and (xvii) “Transmission Services Agreement” or “TSA” means the agreement titled ‘Transmission Services Agreement dated [Insert Date of the TSA] entered into between the Central Transmission Utility of India Limited (CTUIL) and _______ (Insert the name of SPV) pursuant to which the TSP shall build, own, operate and Transfer the Project and make available the assets of the Project on a commercial basis. 1.3 Interpretation Clause Unless the context otherwise requires, the provisions of the TSA relating to the interpretation of the TSA shall apply to this Agreement as if they were set out in full in this Agreement and to this end are incorporated herein by reference. 4 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement 2. TRANSFER OF SHARES 2.1 Subject to the terms and conditions of this Agreement, the Shares Seller agrees to sell and transfer to the Selected Bidder and the Selected Bidder hereby agrees to purchase from the Shares Seller, the Sale Shares free from Encumbrances together with all assets and liabilities of the Company with rights and benefits attached thereto in consideration of the Acquisition Price and the covenants, undertakings and the agreements of the Selected Bidder contained in this Agreement. 2.2 The Shares Seller hereby undertakes to cause the Nominees to transfer part of the Sale Shares held by them as nominees of the Shares Seller to the Selected Bidder and execute any documents required to deliver good title to the Sale Shares to the Selected Bidder. 3. CLOSING 3.1 Prior to the Closing Date, the Selected Bidder shall provide to the Shares Seller, valid share transfer forms duly stamped with requisite amount of stamp duty payable on the transfer of the Sale Shares (“Share Transfer Forms”). 3.2 On the Closing Date, the Shares Seller shall hand over to the Selected Bidder or its authorised representative, the original share certificates representing the Sale Shares (“Sale Share Certificates”) executed by the Shares Seller and the Nominees, simultaneously against the Selected Bidder handing over to the Shares Seller, demand drafts drawn in favour of the Shares Seller or by confirmation of RTGS transfer in favour of the Shares Seller, for the Acquisition Price payable to it. Provided that prior to the handing over of the Sale Share Certificates to the Selected Bidder as mentioned above, the Selected Bidder shall provide satisfactory evidence to REC PDCL that on the Closing Date, the Selected Bidder has furnished the Contract Performance Guarantee to the Central Transmission Utility of India Limited (CTUIL) and is in a position to comply with all other requirements of Clause 2.15.2 of the RFP. 3.3 The Selected Bidder shall immediately upon receiving the Sale Share Certificates and the Share Transfer Forms, duly execute the Share Transfer Forms and duly lodge the Share Transfer Forms and the Share Certificates with the Company along with the names of its nominees to be appointed on the Board of the Company and the address within the jurisdiction of the RoC of New Delhi and Haryana, which would be the new registered office of the Company. The Company shall, upon receipt of the said documents from the Selected Bidder, do the following: (i) Immediately on the Closing Date convene a meeting of the Board, wherein the Board shall pass the following necessary resolutions: 5 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement (a) approving the transfer of the Shares constituting the Sale Shares from the Shares Seller and the Nominees to the name of the [Insert Name of the Selected Bidder] and transfer of all assets and liabilities of the Company as on Closing Date; (b) approving the [Insert Name of the Selected Bidder] as a member of the Company and entering the name of the [Insert Name of the Selected Bidder] and its nominees in the register of members. (c) changing the address of the registered office of the Company to the new address as provided by the Selected Bidder as per clause 3.3 above. (d) appointing the nominees of the Selected Bidder on the Board and accepting the resignations of the other existing Directors on the Board and the Chair of the meeting which was taken by one of the existing Directors shall be vacated and appointment of a new Chairman who shall be one of the newly appointed Director, for the rest of the meeting. Immediately pursuant to the acceptance of resignation of the existing Directors and appointment of new Chairman, the newly constituted Board of Directors shall continue with the meeting and pass the following resolution: (e) terminating all the authorizations granted regarding the business and/or operations of the Company or the operations of the bank accounts of the Company, with prospective effect; and (f) acknowledging and accepting the terms and conditions as contained in the executed copies of the RFP Project Documents and to abide by the provisions contained therein. (ii) Enter the name of the [Insert Name of the Selected Bidder] and its nominees as the legal and beneficial owner of the Sale Shares, free of all Encumbrances, in the register of members of the Company; (iii) Make the necessary endorsements on the Sale Share Certificates, indicating the name of the [Insert Name of the Selected Bidder] and its nominees as the legal and beneficial owner of the Sale Shares evidenced there under; 6 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement (iv) Return the original Sale Share Certificates, duly endorsed in the name of the [Insert Name of the Selected Bidder]a nd its nominees, to the [Insert Name of the Selected Bidder] and its nominees, as the case may be or its authorised representative; (v) Handover all the statutory registers and records, if any, of the Company to the Selected Bidder. (vi) Handover certified true copies of the Board resolution passed by the Company as per (i) (a) to (i) (f) of Clause 3.3 (i) to the Central Transmission Utility of India Limited (CTUIL) 3.4 The Parties to this Agreement agree to take all measures that may be required to ensure that all the events contemplated in the Clauses 3.1 to 3.3 above on the Closing Date are completed on the same day. Notwithstanding the provisions of Clause 3.3 hereto, all proceedings to be taken and all documents to be executed and delivered by the Parties at the Closing Date shall be deemed to have been taken and executed simultaneously and no proceedings shall be deemed to have been taken nor documents executed or delivered until all have been taken, executed and delivered. 3.5 The Selected Bidder hereby acknowledges and agrees that after the date of acquisition of one hundred percent (100%) of the Shares of the Company by the Selected Bidder as per Clause 3.3, (a) the authority of the BPC in respect of the Bid Process shall forthwith cease and any actions to be taken thereafter regarding the Bid Process will be undertaken by the Central Transmission Utility of India Limited (CTUIL), (b) all rights and obligations of the BPC shall cease forthwith, (c) all other rights and obligations of the Company shall be of the TSP and (d) any decisions taken by the BPC on behalf of the Company prior to the date of acquisition, shall continue to be binding on the Company and/or Central Transmission Utility of India Limited (CTUIL) as the case may be. 3.6 This Agreement shall be effective from the date of its signing by the Parties and shall remain in force until all the obligations of the respective Parties under Clause 3.3 hereto are fulfilled. 4. REPRESENTATIONS AND WARRANTIES 4.1 The Selected Bidder hereby represents and warrants to the Shares Seller that: 4.1.1 The Selected Bidder has full legal right, power and authority to enter into, execute and deliver this Agreement and to perform the obligations, undertakings and transactions set forth herein, and this Agreement has been duly and validly executed and delivered by the Selected Bidder and constitutes its legal, valid and binding obligations, enforceable against it in accordance with its terms; 7 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement 4.1.2 The execution, delivery and performance of this Agreement by the Selected Bidder will not violate or contravene any provision of the Memorandum of Association or Articles of the Selected Bidder, (ii) will not violate or contravene any law, statute, rule, regulation, licensing requirement, order, writ, injunction or decree of any court, governmental instrumentality or other regulatory, governmental or public body, agency or authority by which the Selected Bidder is bound or by which any of its and/or their properties or assets are bound, and (iii) except to the extent that the same have been duly and properly completed or obtained, will not require any filing with, or permit, consent or approval of or license from, or the giving of any notice to, any court, governmental instrumentality or other regulatory, governmental or public body, agency or authority, joint venture party, or any other entity or person whatsoever; and 4.1.3 The Selected Bidder is not restricted in any manner whatsoever, including without limitation, on account of any judicial or governmental order, action or proceeding, or any contractual obligation assumed by the Selected Bidder, from purchasing the Sale Shares from the Shares Seller in the manner provided for in this Agreement. 4.2 The Shares Seller hereby represents and warrants to the Selected Bidder that; 4.2.1 The Shares Seller and the Nominees are the legal and beneficial owners of the Sale Shares, free and clear of any Encumbrance and the delivery to the Selected Bidder of the Sale Shares pursuant to the provisions of this Agreement will transfer to the Selected Bidder a good title to the Sale Shares. 4.2.2 The Shares Seller has full legal right, power and authority to enter into, execute and deliver this Agreement and to perform the obligations, undertakings and transactions set forth herein. The execution, delivery and performance of this Agreement will not violate the Memorandum and Articles of Association of the Shares Seller or contravene any contract by which it is bound. 4.2.3 The Shares Seller has obtained requisite authorizations to sell and transfer the Sale Shares to the Selected Bidder. The Shares Seller also represent that it is not prevented from transferring and selling the Sale Shares. Also, to the best of its knowledge, the Sale Shares are not the subject matter of any claim or pending proceeding or threatened by any legal proceeding made by any third party. 8 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement 4.3 Except as specified in Clause 4.2 above, the Shares Seller shall not be deemed to have, made any representation or warranty whatsoever, whether express or implied, in relation to the Sale Shares or Company, including but not limited to any implied warranty or representation as to the business or affairs of Company. 4.4 The Representations and Warranties are given as at the date of this Agreement except that where a Representation and Warranty is expressed to be made as at another date, the Representation and Warranty is given with respect to that date only. 4.5 Each Representation and Warranty is to be construed independently of the others and is not limited by reference to any other Warranty. The Representations, Warranties and undertakings contained in this Clause 4 hereto or in any document delivered pursuant to or in connection with this Agreement are continuing in nature and shall survive the Closing Date for a period of one (1) year. 4.6 The Parties represent to each other that all Representations and Warranties provided herein by the respective Party shall be true as of Closing Date. 5. OBLIGATIONS OF THE SELECTED BIDDER The Selected Bidder agrees that the Shares Seller shall not be liable in any manner, nor shall it assume any responsibility or liability whatsoever, in respect of the business of the Company and its operations or activities, arising after the Closing Date, to any Person or any authority, central, state, local or municipal or otherwise and the same shall be the sole responsibility of the Selected Bidder. 6. MISCELLANEOUS 6.1 NOTICES a) All notices to be given under this Agreement shall be in writing and in the English language. b) All notices must be delivered personally or by registered or certified mail or by recognised courier to the addresses below: Selected Bidder: [Insert details of the address for correspondence] (Lead Member in case of Consortium) REC PDCL: REC Power Development and Consultancy Limited 9 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi-110003 Company: _____________ (name of SPV) Core-4, SCOPE Complex, 7, Lodhi Road, New Delhi-110003 c) Any Party may by notice of at least fifteen (15) days to the other Parties change the address and / or addresses to which such notices and communications to it are to be delivered or mailed. 6.2 RESOLUTION OF DISPUTES 6.2.1 If any dispute arises between the Parties, in connection with the validity, interpretation, implementation or alleged breach of any provision of this Agreement (“Dispute”), the disputing Parties hereto shall endeavour to settle such Dispute amicably. The attempt to bring about an amicable settlement shall be considered to have failed if not resolved within sixty (60) days from the date of the Dispute. 6.2.2 If the Parties are unable to amicably settle the Dispute in accordance with Clause 6.2.1 within the period specified therein, any of the Parties shall be entitled to within thirty (30) days after expiry of the aforesaid period, refer the Dispute to the Company Secretary of REC PDCL and Chief Executive/ Managing Director of the Selected Bidder for resolution of the said Dispute. The attempt to bring about such resolution shall be considered to have failed if not resolved within thirty (30) days from the date of receipt of a written notification in this regard. 6.2.3 In the event the Dispute is not settled in accordance with Clause 6.2.2 above, any Party to the Dispute shall be entitled to serve a notice invoking this Clause and making a reference to a sole arbitrator. If the Parties to the Dispute cannot agree as to the appointment of the sole arbitrator within thirty (30) days of receipt of the notice of the Party making the reference, then the Shares Seller along with the Company shall appoint one arbitrator and the Selected Bidder shall appoint one arbitrator and the two arbitrators, so appointed shall appoint a third arbitrator. However, after the Closing Date, in such an event the Shares Seller shall appoint one arbitrator and the Selected Bidder along with the Company shall appoint one arbitrator and the two arbitrators, so appointed shall appoint the third arbitrator. 6.2.4 The place of the arbitration shall be New Delhi. The Arbitration proceedings shall be governed by the Arbitration and Conciliation Act, 1996. 10 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement 6.2.5 The proceedings of arbitration shall be in English language. 6.2.6 The arbitrator’s award shall be substantiated in writing. The arbitrators shall also decide on the costs of the arbitration proceedings. In case the arbitrators have not decided on the costs of the arbitration proceedings, each Party to the Dispute shall bear its own costs, in relation to the arbitration proceedings. 6.3 AUTHORISED PERSON For the purposes of this Agreement, the Selected Bidder is represented by [Insert Name of the authorized representative of the Selected Bidder/ Lead Member, in case of Consortium], pursuant to an authorization granted to ___[Insert Name of the authorized representative of the Selected Bidder/Lead Member, in case ofC onsortium] through necessary Board resolutions. Further, ___ [Insert Name of the authorized representative of the Selected Bidder/Lead Member, in case of Consortium] is also authorized by such resolutions to take any decision which may be required to be taken, do all acts and execute all documents which are or may be required by the Selected Bidder for the proper and effective fulfillment of the rights and obligations under this Agreement. Any action taken or document executed by [Insert Name of the authorized representative of the Selected Bidder/Lead Member, in case of Consortium] shall be deemed to be acts done or documents executed by the Selected Bidder and shall be binding on the Selected Bidder. 6.4 RESERVATION OF RIGHTS No forbearance, indulgence or relaxation or inaction by any Party at any time to require performance of any of the provisions of this Agreement shall in any way affect, diminish or prejudice the right of such Party to require performance of that provision, and any waiver or acquiescence by any Party of any breach of any of the provisions of this Agreement shall not be construed as a waiver or acquiescence of any continuing or succeeding breach of such provisions, a waiver of any right under or arising out of this Agreement or acquiescence to or recognition of rights other than that expressly stipulated in this Agreement. 6.5 CUMULATIVE RIGHTS All remedies of either Party under this Agreement whether provided herein or conferred by statute, civil law, common law, custom or trade usage, are cumulative and not alternative and may be enforced successively or concurrently. 11 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement 6.6 PARTIAL INVALIDITY If any provision of this Agreement or the application thereof to any person or circumstance shall be invalid or unenforceable to any extent, the remainder of this Agreement and the application of such provision to persons or circumstances other than those as to which it is held invalid or unenforceable shall not be affected thereby, and each provision of this Agreement shall be valid and enforceable to the fullest extent permitted by law. Any invalid or unenforceable provision of this Agreement shall be replaced with a provision, which is valid and enforceable and most nearly reflects the original intent of the unenforceable provision. 6.7 TERMINATION If (i) the Closing does not occur on the Closing Date for any reason whatsoever, or (ii) the Letter of Intent is withdrawn or terminated for any reason, or (iii) due to termination of the TSA by the Central Transmission Utility of India Limited (CTUIL) in accordance with Article 3.3.2 or Article 13 of the TSA thereof, REC PDCL shall have a right to terminate this Agreement forthwith by giving a written notice to the other Parties hereto. 6.8 AMENDMENTS No modification or amendment of this Agreement and no waiver of any of the terms or conditions hereof shall be valid or binding unless made in writing and duly executed by all the Parties. 6.9 ASSIGNMENT This Agreement and the rights and liabilities hereunder shall bind and inure to the benefit of the respective successors of the Parties hereto, but no Party hereto shall assign or transfer its rights and liabilities hereunder to any other Person without the prior written consent of the other Parties, which will not be unreasonably withheld. 6.10 ENTIRE AGREEMENT This Agreement constitutes the entire Agreement between the Parties with respect to the subject matter herein and supersedes and cancels any prior oral or written agreement, representation, understanding, arrangement, communication or expression of intent relating to the subject matter of this Agreement. 6.11 COSTS Each of the Parties hereto shall pay their own costs and expenses relating to the negotiation, preparation and execution of this Agreement and the transactions contemplated by this Agreement. 12 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement The Selected Bidder shall be liable to bear and pay the costs in respect of this Agreement and transfer of Sale Shares. 6.12 RELATIONSHIP None of the provisions of this Agreement shall be deemed to constitute a partnership between the Parties hereto and no Party shall have any authority to bind the other Party otherwise than under this Agreement or shall be deemed to be the agent of the other in any way. 6.13 GOVERNING LAW AND JURISDICTION This Agreement shall be governed by and construed in accordance with the laws of India and shall be subject to the exclusive jurisdiction of the courts of Delhi. 6.14 COUNTERPARTS This Agreement may be executed in counterparts by the Parties and each fully executed counterpart shall be deemed to be original. 6.15 CONFIDENTIALITY The Parties undertake to hold in confidence and not to disclose the terms and conditions of the transaction contemplated hereby to third parties, except: (a) to their professional advisors; (b) to their officers, employees, agents or representatives, who need to have access to such information for the proper performance of their activities; (c) disclosures required under Law; without the prior written consent of the other Parties. Provided that the Central Transmission Utility of India Limited (CTUIL) and REC PDCL may at any time, disclose the terms and conditions of transactions contemplated hereby to any person, to the extent stipulated under the law or the Bidding Guidelines. 6.16 INDEMNIFICATION The Parties hereby agree that transfer of Sale Shares to the Selected Bidder shall vest all the rights, privileges, licenses, responsibilities, liabilities and other obligations pertaining to the Company in the Selected Bidder. 13 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement  The Selected Bidder hereby agrees that the Selected Bidder shall not be entitled to any claims or initiate any legal proceedings by itself or through the Transmission Service Provider against the Share Sellers, its directors, officers, employees and the subscribers including the members of any committees appointed by them in respect of any actions or decisions taken by any of them up to the Closing Date in furtherance of the Project referred to in recital A of this Agreement.  Further, the Selected Bidder hereby indemnifies and holds harmless at all times the Share Seller against all past, present and future third party claims and liabilities arising out of actions or decisions taken by any of the persons or bodies referred to in Clause 6.3 up to the Closing Date in furtherance of the Project referred to above or otherwise concerning the Company. All such actions shall be defended by the Selected Bidder either itself or through the TSP at its own cost.  The Parties hereby agree that the provisions of this clause shall survive the termination of this Agreement. 6.17 SURVIVAL The provisions of Clause 1 (Definitions and Interpretation), Clause 4 (Representations and Warranties), Clause 6.2 (Dispute Resolution), Clause 6.7 (Termination), Clause 6.15 (Confidentiality), Clause 6.16 (Indemnification) and other representations, warranties, covenants and provisions contained herein that by their nature are intended to survive, shall survive the termination of this Agreement 6.18 FORCE MAJEURE No party shall be liable for its inability or delay in performing any of its obligations hereunder if such delay is caused by circumstances beyond the reasonable control of the party including delay caused through flood, riot, Act of God, lighting civil commotion, storm, tempest and earthquake. 14 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement IN WITNESS WHEREOF, THE PARTIES HERETO HAVE CAUSED THIS AGREEMENT TO BE DULY EXECUTED AND DELIVERED AS OF THE DAY AND YEAR FIRST ABOVE WRITTEN SIGNED AND DELIVERED by The within named REC Power Development and Consultancy Limited by the hand of Sh. authorised pursuant to the resolution passed by its board of directors in its meeting held on IN THE PRESENCE OF: WITNESS: 1. 2. (name and address) SIGNED AND DELIVERED by The within named ………………… (Name of SPV) by the hand of Sh. , its Chairman, authorised pursuant to the resolution passed by its board of directors in its meeting held on IN THE PRESENCE OF WITNESS: 1. 2. (name and address) SIGNED AND DELIVERED by The within named [insert name of the selected bidder] by the hand of Sh. , its , authorised pursuant to the resolution passed by its board of directors in its meeting held on IN THE PRESENCE OF: WITNESS: (Name and Address) 15 RECPDCL [Name of SPV] [Selected Bidder]Share Purchase Agreement ANNEXURE A DESCRIPTION OF THE SALE SHARES NUMBER OF PERCENTAGE OF S. EQUITY THE TOTAL PAID NAME OF THE SHAREHOLDER NO. SHARES UP EQUITY HELD CAPITAL REC Power Development and 1. Consultancy Limited through its 49,994 99.988 2. 1 0.002 3. 1 0.002 4. 1 0.002 5. 1 0.002 6. 1 0.002 7. 1 0.002 Total 50,000 100.000 *Held as nominee of RECPDCL 16 RECPDCL [Name of SPV] [Selected Bidder]