Settlement system under Open Access Terms

Settlement system under Open Access

Terms & meaning • Open Access – Non-discriminatory Access to Tr. System Nodal RLDC – RLDC where the Drawee utility is located Applicant - Who applies for OA Customer - Who is granted OA

Category of OA Tx. • Advance - Reservation of Cap. up to a max. of 3 months (for each month) • First Come First Serve – Reservation of Cap. if any, after allotment to Adv. Applicants (upto a max of next 3 months) • Day Ahead/ Reservation of Cap. On Day ahead/ • Contingency - Reservation of Cap. On Day ahead/ same day basis, if any after allotment to Day Ahead

Philosophy • • • To avoid pan-caking of charges Reduce cost of power/ burden on end user Encourage transactions Reasonable levy of charges for the usage Fair compensation to the Long term user of Tr. System • Fair compensation to the Owner of Tr. System • Reasonable charges to RLDC/SLDCs

Processing of Advance Applications for next 3 months 10/5/1 day (17. 30 hrs) prior in a month for 2 nd/3 rd/4 th month Dead Line for Receipt of Application Request for Consent from SLDC/RLDC Next Day to due date(12. 00 hrs) SAME DAY 20. 00 HRS Issue of Consent by SLDC/RLDC WITHIN 5 DAYS No Approval Next day 12. 00 hrs Yes Check for any Tr. Congestion ? No Still Tr. Congestion ? Request Applicant for a revised Tr. Cap. Next day 12. 00 hrs Next day Revised MW/Duration 11. 00 hrs by Applicant Yes 4 th day after due date WITHIN 5 DAYS E-bidding Approval 3 working days after issue. Commence. Payment of ment STOA ch. of Tx.

Non-utilisation of Reserved Tr. Capacity Non-utilization (full/substantial) by Customer Suo-Motu by Nodal RLDC Intimation by Customer To Nodal RLDC Notice to Customer 1 day Revised Approval Forfeit of STOA ch. For 2 days/ balance period of Tx. Reallottment to Another Applicant

Curtailment in case of Tr. constraint Curtailment? No Yes No refund Refund Pro-rata Charges of Curtailed Capacity

Settlement of Energy Charges Trader Energy Charges Seller Buyer Trader’s commission charges Trader

Settlement of STOA Charges Nodal RLDC Application fee STU/ licensee charges All STUs involved 75% to Long term Customers Nodal RLDC Is OA Granted? CTU ISTS+ IR link charges CTU 25%of ISTS to CTU for Augmentation Yes Operating Charges For RLDCs Operating Charges For SLDCs All RLDCs involved All SLDCs involved

Bilateral Transaction charges • 1) Application fee Rs. 5000 per each transaction (Nonrefundable) • Along with application for Adv/FCFS • Within 3 working days for DA/Contingency 2) Transmission Charges a) Regional/CTU Tr. Ch. Rs. 80/MWh (ps 8/u) for within region Rs. 160/MWh (ps 16/u) for b/w adjoining regions Rs. 240/MWh (ps 24/u) for wheeling by one or more regions b) STU/SEB/Tr. Licencee Tr. Ch. To be paid only if the Tx is not internalised. as specified by SERC or Rs. 80/MWh (ps 8/u)

Bilateral Transaction charges • Operating Charges • Rs. 2000/day for each Tx. – For each RLDC involved – For each SLDC involved (only if not internalised)

Internalisation • Mostly in case where unbundling has not take place ( ex. SEBs, vertically integrated utilities etc. ) • For own use, Tx is internalised • For use by a third party, Not internalised. If internalised • Certificate to be submitted • No transmission charges for concerned STU/Tr. Licencee • No operating charges for concerned SLDC

Mode of payment to Nodal RLDC • Bank draft/ at par cheque/ electronic money transfer • No outstation cheque • Within 3 working days • Transaction-wise payment details to be submitted in Format -VII

Default • 0. 04% simple interest for each day of delay/default • Nodal RLDC may not – schedule the Transaction – Entertain further application in future till dues are cleared

Other Charges • 1) Energy charges • As negotiated mutually based on market conditions, demand-supply position • Rate need not be disclosed to RLDCs • To be directly settled between buyer /seller • Trader to collect and disburse • May be influenced by losses, trading marigin etc. • Charged on energy as reflected in monthly REA • REA to furnish figures @Buyer/seller periphery, IR periphery, Peak/offpeak , Discomwise etc.

Other Charges • Trading marigin @4 ps/u if cost of power =< ps 350/u @ 7 ps/u if cost of power > ps 350/u

Revision in OA schedule • Only for Advance/ FCFS • Min. 2 days notice/request excluding the day of revision • Scheduled OA charges for 2 days to be foregone • OA charges corresponding to Downward revision to be refunded • To be reconciled for previous month and refunded within 15 days of current month

Disbursement Nodal RLDC to • Reconcile all charges for previous month • Disburse to all stake holders within 10 days in current month Disbursement of • CTU charges to concerned RTS • STU charges to concerned STU/SEB • Operating charges to concerned RLDCs • Operating charges to concerned SLDCs

Disbursement RTS • to retain 25% of CTU transmission charges • Balance 75% to give credit in their Transmission Bill (as per weighted Average entitlement to each Long term customer)

Refund When to refund ? • A) Incase of curtailment due to transmission constraints • B) Incase of revision in Schedule How much to refund ? • A) Pro-rata charges for the energy curtailed • B) Retain a minimum of five days of OA charges(Tr and Op ch. ) and Refund balance OA charges (transmission charges and operating charges) for the reduction in Energy Deadline for Refund : • Within 15 days of current month for Tx curtalied/revised in previous month

Indemnification No responsibility to Nodal RLDC • In case of Default Indemnify RLDC/ SLDC harmless from All damages/ losses/ claims/ costs etc.

Internalization • As Declared in the Application Buyer/Seller is said to be internalised : • If they are Directly connected to CTU (ex. SEBs, CGS etc. ) • In case of an Embedded Customer where The Connected STU is not yet unbundled • In case of organizations where full commercial separation is not in place • When STU charges and losses are not published • If the power purchase rate includes the Tr. Ch. And Losses Implications if internalised : – No Transmission charges – No Scheduling/ operating charges – No Normative Losses

Non-Internalization • As Declared in the Application Buyer/Seller is said to be Not Internalised • If Buyer/Seller is embedded customer (CPP, IPP, HT consumer etc. ) – in a not-yet unbundled SEB – In an unbundled state setup case • If Buyer/Seller is a Power purchase centre, Discom in an unbundled setup Implications if Not internalised : – Transmission charges to be paid – Scheduling/ operating charges to be borne – Normative Losses applicable

Normative Losses for Scheduling STOA • AP: 4. 2% KPTCL: 4. 06% • DVC: 2. 82% WB: 3. 9% • DTL: 1. 5% CSEB: 4. 03% • MP: 4. 9% Maharashtra: 4. 85% • OPTCL: 4. 5%Rajasthan: 4. 4% only for Embedded • KSEB: 0. 75% TNEB: 1. 75%

STOA OF KSEB(KYCPP) - TNEB 0000 HRS – 2400 HRS 150 MW AT KYCPP EXBUS POINT for 31 days CUSTOMER: TNEB TRADER: - INJECTING UTILITY : KYCPP, (KSEB) LA RA KE (Not Internalised) DRAWEE UTILITY TNEB (Internalised) CAPACITY APPROVED DAILY PERIOD TAMILNADU 150 MW 0000 -2400 HRS DATE OF COMMENCEMENT 01 -10 -08 DATE OF EXPIRY 31 -10 -08 KAYAMKULAM CCGT(NTPC)

STOA OF KSEB(KYCPP) - TNEB 0000 HRS – 2400 HRS 150 MW AT KYCPP EXBUS POINT for 31 days FROM 01 -08 -07 TO 31 -08 -07, THROUGHOUT THE DAY APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION 1. Rs 2000 FOR SRLDC 2. Rs 2000 FOR KSEB TRANSMISSION CHARGES PER MW PER DAY 1. Rs 30/ MWh LA RA KE SCHEDULING CHARGES PER DAY TAMILNADU FOR CTU-SR 2. Rs 30/ MWh FOR KERALA TOTAL TRANSMISSION CHARGE PER UNIT 6. 12/. Ps MORE DETAILS KAYAMKULAM CCGT(NTPC)

STOA OF WBSEB - PCKL (0000 – 1700 & 2300 – 2400 HRS) 50 MW AT INJECTION POINT FOR 21. 11. 08 CUSTOMER: NVVN TRADER: NVVN INJECTING UTILITY WBSEB WB (Not Internalised) DRAWEE UTILITY ER PCKL HVDC BACK TO BACK AT GAZUWAKA IN SR (Not Internalised) INTERVENING REGIONAL LINK DAILY PERIOD ER-SR 0000 -1700 & 2300 -2400 HRS CAPACITY APPROVED SR 50 MW CTU DATE OF COMMENCEMENT 21 -11 -08 DATE OF EXPIRY 21 -11 -08 KAR

STOA OF WBSEB - PCKL (0000 – 1700 & 2300 – 2400 HRS) 50 MW AT INJECTION POINT FOR 21. 11. 08 EXPORT AT WB LOSSES IN WB AT ER- WB PERIPHERY 50 MW 4% 48 MW LOSSES IN ER 3% AT ER-SR PERIPHERY WB 46. 56 MW LOSSES IN SR HVDC BACK TO BACK AT GAZUWAKA IN SR 3. 67% AT KPTCL PERIPHERY LOSSES IN KPTCL ER 44. 85 MW 4. 06% PCKL RECEIVES TOTAL LOSSES FOR TRANSACTION 43. 23 MW 2. 77 MW SR CTU KAR

STOA OF WBSEB - PCKL (0000 – 1700 & 2300 – 2400 HRS) 50 MW AT INJECTION POINT FOR 21. 11. 08 APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION SCHEDULING CHARGES PER DAY 1. Rs 2000 FOR WBLDC 2. Rs 2000 FOR ERLDC 3. Rs 2000 FOR SRLDC WB 4. Rs 2000 FOR Karnataka LDC TRANSMISSION CHARGES PER MWh PER DAY 1. Rs 30/MWh ER HVDC BACK TO BACK AT GAZUWAKA IN SR FOR WBTCL 2. Rs 30/MWh FOR CTU-ER 3. Rs 30/MWh FOR CTU-SR 4. Rs 32. 833/MWh FOR KPTCL TOTAL TRANSMISSION CHARGE PER UNIT 12. 2833 Ps/U SR CTU KAR

MPTRADECO-APPCCB THROUGH LANCO (1200 HRS – 1800 HRS) 100 MW AT INJECTION POINT for 26. 08 CUSTOMER: LANCO TRADER: INJECTING UTILITY MP LANCO MPTRADECO (Not Internalised) DRAWEE UTILITY WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR APPCC (Not Internalised) INTERVENING REGIONAL LINK 1. WR-SR AP CAPACITY APPROVED DAILY PERIOD 100 MW 1200 -1800 HRS DATE OF COMMENCEMENT 26 -08 -08 DATE OF EXPIRY 26 -08 -08

MPTRADECO-APPCCB THROUGH LANCO (1200 HRS – 1800 HRS) 100 MW AT INJECTION POINT for 26. 08 EXPORT AT MP 100 MW LOSSES IN MP 4% AT MP PERIPHERY 96. 0 MW AT WR-SR PERIPHERY LOSSES IN SR AT SR-AP PERIPHERY LOSSES IN AP APPCC RECIEVES 4% 92. 16 MW 4. 05% HVDC BACK TO BACK AT BHADRWATHI IN WR 88. 83 MW 4. 53% 84. 42 MW TOTAL LOSSES FOR TRANSACTION WR GRID CT U LOSSES IN WR MP 15. 57 MW AP

MPTRADECO-APPCCB THROUGH LANCO (1200 HRS – 1800 HRS) 100 MW AT INJECTION POINT for 26. 08 APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION SCHEDULING CHARGES PER DAY 1. Rs 2000 FOR MP SLDC 2. Rs 2000 FOR WRLDC 3. Rs 2000 FOR SRLDC 4. Rs 2000 FOR APLDC MP WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR TRANSMISSION CHARGES PER MW PER DAY 1. Rs. 30/MWh FOR MPTCL 2. Rs 30/MWH FOR WR CTU 3. Rs 30/MWH FOR SR CTU 4. Rs 53. 3/MWH FOR APTRANSCO TOTAL TRANSMISSION CHARGE PER UNIT 14. 33 Ps/U. AP

STOA OF BANNARI AMMAN SUGARS -APPCC, 10 MW FROM 0000 HRS – 2400 HRS FROM 09 -11 -08 TO 12 -11 -08 CUSTOMER: TATA TRADER: TATA INJECTING UTILITY BANNARI AMMAN SUGARS (KPTCL) (Not Internalised) DRAWEE UTILITY AP APPCC (Not Internalised) INTERVENING REGION CAPACITY APPROVED DAILY PERIOD KAR SR 10 MW 0000 HRS – 2400 HRS DATE OF COMMENCEMENT 09 -11 -08 DATE OF EXPIRY 12 -11 -08

STOA OF BANNARI AMMAN SUGARS -APPCC, 10 MW FROM 0000 HRS – 2400 HRS FROM 09 -11 -08 TO 12 -11 -08 EXPORT AT BANNARI LOSSES IN KARNATAKA AT KPTCL PERIPHERY LOSSES IN SR AT AP PERIPHERY LOSSES IN AP AT AP PERIPHERY 10 MW 4. 06% 9. 594 MW 3. 45% AP 9. 263 MW 4. 53% 9. 263 MW TOTAL LOSSES FOR TRANSACTION 11. 56 MW KAR

STOA OF BANNARI AMMAN SUGARS -APPCC, 10 MW FROM 0000 HRS – 2400 HRS FROM 09 -11 -08 TO 12 -11 -08 APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION SCHEDULING CHARGES PER DAY 1. Rs 2000 FOR KP LDC 2. Rs 2000 FOR SRLDC 3. Rs 2000 FOR AP LDC TRANSMISSION CHARGES PER MW PER DAY AP KAR 1. Rs. 32. 833/ MWh FOR KPTCL 2. Rs 30 / MWH FOR CTU-SR 3. Rs 53. 3 / MWH FOR APTRANSCO TOTAL TRANSMISSION CHARGE PER UNIT 11. 6133 Ps. /U

CALCULATION FOR THE SHORT TERM CUSTOMER FOR THE TRANSACTION OF KYCPP – TNEB OF NVVNL (150 MW) BACK

DVC – Jaipur WHEEL THROUGH SR (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW FROM 01. 08 to 31. 08 CUSTOMER: TATA TRADER: TATA INJECTING UTILITY HVDC BACK TO BACK AT VINDHYACHAL IN WR RAJASTHAN DVC JAIPUR (Not Internalised) DRAWEE UTILITY WB NR JAIPUR (DISCOM) (Not Internalised) INTERVENING REGION DVC ER WR SR & WR INTERVENING REGIONAL LINK : ER-SR SR-WR WR-NR HVDC BACK TO BACK AT BHADRWATHI IN WR INTERVENING STATE TRANSMISSION UTILITY RRVPN CAPACITY APPROVED 50 MW DAILY PERIOD 0000 -1700 & 2300 -2400 hrs DATE OF COMMENCEMENT DATE OF EXPIRY 01 -01 -08 31 -01 -08 SR HVDC BACK TO BACK AT GAZUWAKA IN SR

DVC – Jaipur WHEEL THROUGH SR, WR (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW FROM 01. 08 to 31. 08 EXPORT AT DVC LOSSES IN DVC 2. 82% AT ER-SR PERIPHERY LOSSES IN ER 48. 59 MW 3% AT ER-SR PERIPHERY LOSSES IN SR VINDHYACHAL HVDC & Gwalior-Agra 50 MW NR RAJASTHAN AJMER WB DVC 47. 13 MW 4. 0% AT SR-WR PERIPHERY 45. 25 MW LOSSES IN WR ER 4% AT WR-NR PERIPHERY 43. 44 MW LOSSES IN NR HVDC BACK TO BACK AT BHADRWATHI IN WR 3. 5% AT NR-RAJ. PERIPHERY WR 41. 92 MW LOSSES IN RAJASTHAN SR 4. 4% JAIPUR RECIEVES 40. 07 MW TOTAL LOSSES FOR TRANSACTION HVDC BACK TO BACK AT GAZUWAKA IN SR 9. 93 MW

DVC – Jaipur WHEEL THROUGH SR (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW FROM 01. 08 to 31. 08 HVDC BACK TO BACK AT VINDHYACHAL IN WR APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION RAJASTHAN SCHEDULING CHARGES PER DAY 1. Rs 3000 FOR SRLDC 3. Rs 3000 FOR WRLDC 4. Rs 3000 FOR NRLDC 5. Rs 2000 WB DVC FOR ERLDC 2. Rs 3000 AJMER NR FOR RAJASTHAN ER WR HVDC BACK TO BACK AT BHADRWATHI IN WR SR HVDC BACK TO BACK AT GAZUWAKA IN SR

DVC – Jaipur WHEEL THROUGH SR (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW FROM 01. 08 to 31. 08 HVDC BACK TO BACK AT VINDHYACHAL IN WR TRANSMISSION CHARGES Rs. /MW/Day 1. Rs 647 FOR CTU-ER 2. Rs 1909 FOR ER-SR LINK 3. Rs 843 FOR CTU-SR 4. Rs 1311 FOR SR-WR LINK 5. Rs 357 FOR CTU-WR 6. Rs 600 FOR WR-NR LINK RAJASTHAN AJMER NR WB DVC ER WR HVDC BACK TO BACK AT BHADRWATHI IN WR 7. Rs 594 FOR CTU-NR 8. Rs 3159 FOR STU-RAJASTAN TOTAL TRANSMISSION CHARGE PER UNIT (AS PER PRESENT RATES 22. 12 Ps/U) 39. 25 Ps/U SR HVDC BACK TO BACK AT GAZUWAKA IN SR

Dadri URS Power– AP through ER (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW on 21. 11. 08 CUSTOMER: NVVN TRADER: NVVN INJECTING UTILITY NR DADRI WB AJMER (Internalised) DRAWEE UTILITY ER APPCC (Not Internalised) INTERVENING REGION ER INTERVENING STATE TRANSMISSION UTILITY APTRANSCO CAPACITY APPROVED 50 MW DATE OF COMMENCEMENT DATE OF EXPIRY AP 21 -11 -08 HVDC BACK TO BACK AT GAZUWAKA IN SR

Dadri URS Power– AP through ER (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW on 21. 11. 08 EXPORT AT Dadri LOSSES IN NR 50 MW 4. 5 % AT NR-ER PERIPHERY LOSSES IN ER 47. 75 MW 3. 4% AT ER-SR PERIPHERY LOSSES IN SR NR DADRI WB AJMER ER 46. 12 MW 3. 67% AT CTU-AP PERIPHERY LOSSES IN AP AT AP DISCOMS RECIEVE 44. 43 MW 4. 2% 42. 57 MW AP TOTAL LOSSES FOR TRANSACTION 7. 43 MW HVDC BACK TO BACK AT GAZUWAKA IN SR

Dadri URS Power– AP through ER (0000 HRS – 1700 HRS AND 2300 -2400 HRS) 50 MW APPLICATION PROCESSING FEE on 21. 11. 08 Rs 5000 PER TRANSACTION NR SCHEDULING CHARGES PER DAY 1. Rs 2000 FOR NBLDC 2. Rs 2000 WB WB FOR ERLDC 3. Rs 2000 DADRI FOR SRLDC AJMER ER ER 4. Rs 2000 FOR AP LDC TRANSMISSION CHARGES PER MWh PER DAY 1. Rs 30/MWh FOR CTU-NR 2. Rs 30/MWh FOR CTU-ER 3. Rs 30/MWh FOR CTU-SR 4. Rs 53. 3/MWh FOR APTRANSCO TOTAL TRANSMISSION CHARGE PER UNIT 14. 33 Ps/U AP HVDC BACK TO BACK AT GAZUWAKA IN SR