Open Access DEFINITION OF OPEN ACCESS IN

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Open Access

DEFINITION OF “OPEN ACCESS” IN THE ELECTRICITY ACT, 2003 “The non-discriminatory provision for the use of transmission lines or distribution system or associated facilities with such lines or system by any licensee or consumer or a person engaged in generation in accordance with the regulations specified by the Appropriate Commission”

INTRODUCTION • Open Access is necessary for utilization of short time surpluses. • Open Access will also create options for distribution companies to buy power. • Open Access will provide means to the traders/buyers/sellers. • Non- discriminatory / Transparent Process • Freedom to buy/sell power • Efficient Market Mechanism to address supply / demand mismatches • Encourage investment in Transmission

Legal Framework SECTION 38: (CTU Function) • CTU to provide open access to Licensee or Generating Company on payment of transmission charge • Any consumer when open access is provided by State Commission on payment of surcharge in addition to transmission charges. • Surcharge shall be for meeting cross subsidy, and to be progressively reduced and eliminated. • Surcharge not payable in case of captive generation and Distribution Companies. • CTU can not engage in generation and trading

Legal Framework Sections 39, 40 and 41 • Similar provisions for STU and Transmission Licensee. • STU can not engage in trading. • Transmission Licensee can not engage in trading Section 42 • State Commission to provide Open Access to all consumers who required supply more than 1 MW in 5 years.

Agencies involved in Short-Term Open Access Transaction • • RLDC (s) SLDC (s) CTU STU (s) Buyer Seller Trader

Open Access – CERC Regulations, 2008

CERC Open Access Regulations, 2008 3. Subject to any other regulations specified by the Commission, the long-term customer shall have first priority for using the inter-State transmission system for the designated use. These Regulations shall apply for utilization of surplus capacity available thereafter on the inter-State transmission system by virtue of(a) Inherent design margins; (b) Margins available due to variations in power flows; (c ) Margins available due to in-built spare transmission capacity created to cater to future load growth or generation addition:

CERC Open Access Regulations, 2008 • Effective 01. 04. 2008 • Regulations cover only Short-term Open Access • Transactions categorized as Bilateral and Collective (through PX) • Earlier Products of Short-Term retained under Bilateral Transactions • Nodal Agency – Bilateral : RLDCs – Collective : NLDC

Open Access in ISTS: CERC OA Regulations 2008 • Both Buyers and Sellers of Collective transactions to bear transmission charges and absorb transmission losses • Inter-Regional links -No Separate treatment. • Emphasis on “Scheduling” rather than “Reservation” • SLDC consent mandated along with application • In case of Congestion – e-Bidding without Price Cap • Exit Option provided with payment of up to 2 days open access charges. • Moving towards empowerment of SLDCs

Open Access in ISTS CERC OA Regulations 2008 • Products – Short term Access - Advance - First Come First Serve - Day ahead - Contingency Long term Access Provisions relating to Long Term as per the Open Access Regulations, 2004 to continue, till CERC further notifies.

Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008) S. No. Old Regulations (06. 05. 2004 to 31. 03. 2005) Amended Regulations (w. e. f. 01. 04. 2005 to 31. 03. 2008) 1. Open Access Duration - Up to One year maximum - Up to Three Months max. - single application possible 2. ST Rate - in Rs/MW/Day - Min. Charges for one day Regulations, 2008 (w. e. f. 01. 04. 2008) Open Access Duration Bilateral -Up to 3 months - separate application for each month Collective: - Only Day ahead ST Rate - in Rs. /MW/Day -in Rs/MWh -Charges as per continuous - Based on Scheduled block of up to 6 hours, Energy rather than 12 hours, and more reservation of transmission than 12 hours capacity

Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008) S. No. Old Regulations (06. 05. 2004 to 31. 03. 2005) Amended Regulations (w. e. f. 01. 04. 2005 to 31. 03. 2008) Regulations, 2008 (w. e. f. 01. 04. 2008) 3. Transmission Charges a. Intra Regional – 25% of Long Term Charges b. Inter Regional – 25% of Long Term Charges Transmission Charges a. Intra Regional – 25% of Long Term Charges b. Inter-Regional - 50% of Long Term Charges Transmission Charges: Bilateral: - Rs. 30/MWh – intra- regional - Rs. 60/MWh – Between adjacent regions - Rs 90/MWh – Wheeling through one or more region Collective Transactions (Px): -Rs. 30/MWh for each point of injection and drawal 4. Operating Charges a. Application fee – Rs. 5000/b. Scheduling Charges – Rs. 3000/day for each RLDC involved – Rs. 3000/day for each SLDC involved c. Handling &Service Charges - 2% of total charges Operating Charges a. Application fee – Rs. 5000/ b. Scheduling Charges – Rs. 3000/day for each RLDC involved – Rs. 1000/day for each RLDC involved c. Handling & Service Charges – Nil Operating Charges Bilateral: a. Application fee – Rs. 5000/b. Scheduling Charges – Rs. 2000/day for each RLDC and SLDC involved c. Handling & Service Charges -Nil Collective Transactions: a. Application fee – Rs. 5000/b. Scheduling Charges – Rs. 5000/day to NLDC for each State involved ; -NLDC to Share with RLDCs

649. 86 516. 03 NORTHERN REGION 233. 32 447. 73 WR-NR 339. 98 359. 68 WESTERN REGION SR-WR 881. 49 1128. 39 967. 58 1795. 11 919. 71 ER-NR NORTHTransmission Charges: EASTERN Bilateral: REGION Rs. 30/MWh – intra- regional 270. 49 Rs. 60/MWh – Between adjacent regions 313. 93 NER-ER 433. 09 Rs 90/MWh – Wheeling through one or 434. 42 ER-WR more. EASTERN region 460. 41 REGION Collective Transactions (Px): 859. 05 -Rs. 30/MWh for each point of injection SR-ER and drawal 1462. 44 2433. 39 2004 SOUTHERN REGION STOA CASE STOA RATES 2004 AND 2005 AND 2008 700. 91 614. 15 Scheduling Charges (Rs/Day) RLDCs SLDCs Handling Charges 2005 2008 3000 1000 2000 2% NIL

STOA CASE APTRANSCO to MPSEB 100 MW for One day from 0000 to 0600 hrs.

APTRANSCO - MPSEB THROUGH NVVNL (0000 HRS – 0600 HRS) 100 MW AT INJECTION POINT CUSTOMER: TRADER: INJECTING UTILITY DRAWEE UTILITY NVVNL MP NVVNL APTRANSCO MPSEB INTERVENING REGIONAL LINK WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR 1. SR-WR CAPACITY APPROVED DAILY PERIOD 100 MW 0000 -0600 HRS AP

APTRANSCO - MPSEB THROUGH NVVNL (0000 HRS – 0600 HRS) 100 MW AT INJECTION POINT EXPORT AT AP LOSSES IN SR 3. 12% AT SR PERIPHERY 96. 9 MW MP 100 MW WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR CT U LOSSES IN WR MP RECIEVES 4% 93. 0 MW AP TOTAL LOSSES FOR TRANSACTION 7. 0 MW

APTRANSCO - MPSEB THROUGH NVVNL (0000 HRS – 0600 HRS) 100 MW AT INJECTION POINT Payments as per Regulation 2004 of CERC APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION MP SCHEDULING CHARGES PER DAY 1. Rs 3000 FOR SRLDC 2. Rs 3000 FOR WRLDC WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR TRANSMISSION CHARGES PER MW PER DAY 1. Rs 700. 91 FOR CTU-SR 2. Rs 881. 49 FOR SR-WR LINK 3. Rs 339. 98 FOR CTU-WR TOTAL TRANSMISSION CHARGE PER UNIT 34. 53 Ps/. AP

APTRANSCO - MPSEB THROUGH NVVNL (0000 HRS – 0600 HRS) 100 MW AT INJECTION POINT Payments as per Regulation 2004 Amendment 2005) of CERC APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION MP SCHEDULING CHARGES PER DAY 1. Rs 3000 FOR SRLDC 2. Rs 3000 FOR WRLDC WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR TRANSMISSION CHARGES PER MW PER DAY 1. Rs 700. 91 FOR CTU-SR 2. Rs 881. 49 FOR SR-WR LINK 3. Rs 339. 98 FOR CTU-WR TOTAL TRANSMISSION CHARGE PER UNIT 13. 52 Ps/. AP

APTRANSCO - MPSEB THROUGH NVVNL (0000 HRS – 0600 HRS) 100 MW AT INJECTION POINT Payments as per Regulation 2008 of CERC APPLICATION PROCESSING FEE Rs 5000 PER TRANSACTION MP SCHEDULING CHARGES PER DAY 1. Rs 2000 FOR SRLDC 2. Rs 2000 FOR WRLDC WR GRID HVDC BACK TO BACK AT BHADRWATHI IN WR TRANSMISSION CHARGES 1. Rs 60 /MWH FOR WHEELING AP TOTAL TRANSMISSION CHARGE PER UNIT 7. 83 Ps/.

Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008) Old Regulations (06. 05. 2004 to 31. 03. 2005) Amended Regulations (w. e. f. 01. 04. 2005 to 31. 03. 2008) Total STOA Charges Paisa/Unit 13. 52 7. 83 34. 53 Regulations, 2008 (w. e. f. 01. 04. 2008)

Procedure for Scheduling of Open Access (Bilateral Transaction)

SUBMISSION OF APPLICATION • Nodal Agency – RLDC where point of drawal is situated • Application Contents – Details -Buyer /Seller /Point of injection/point of drawal/Contracted power at supplier interface/date/time period • Application Fee (Rs. 5000/-) – Along with application – With in 3 working days ( for same day or next day transaction) • Endorsement – Concerned SLDCs

CONCURRENCE OF GRID OPERATORS • Available Transfer Capability • SLDC – ( congestion in intra-State TS) – concurrence -along with Application • RLDC - ( congestion in Regional TS) – To be obtained by Nodal RLDCs • Refusals /Curtailed Concurrence – Reasons to be mentioned in writing

ADVANCE SCHEDULING • Advance Scheduling – 3 months in advance • Separate Application – – Month wise - each transaction • Time Line for submission – Last date for submission ( -10 / -5 / 0 days prior to end of current month M 0 – for transaction in M 1, M 2, M 3) – Cut-off time : 17: 30 Hrs. of last day (Day 0) – Request for concurrence (RLDC) – by 12: 00 Hr. next day (Day 1) – Concurrence - by 20: 00 Hrs (Day 1) – Congestion Information to Applicant – next day 12: 00 Hrs (Day 2) – Revised Request – next day 11: 00 HRs. (Day 3) – E-bidding – in case of Congestion (next day) (Day 4) – Acceptance/Refusal of Scheduling Request – (Day 5)

Time Line for Advance Scheduling M 1 M 0 10 5 Last Day for submission of Applications for transactions in M 1, M 2, M 3 M 2 5 Processing time for RLDCs M 3

e-Bidding Procedure • Invitation of Bids – period of congestion – RTS/IR corridor – overstressed • Only Registered Users – – – • • User ID & Password Electronic submission – website of CTU Bid Closing time as specified Single Price Bid No Modification/withdrawal once submitted Bid Price - in addition to Open Access Transmission Charges Multiples of Rs. 10/ MWh. ( Min. Rs. 10/MWh) Mandatory - Non-participation – Rejection of Application Acceptance - Decreasing order of Price Quoted Equal Price Bids – Pro-rata Part Acceptance – Price as quoted by the bidder Full Acceptance – Price quoted by last bidder getting full acceptance

“FIRST-COME-FIRST-SERVED” BASIS • Scope – Current Month – Next Month ( during last 10 days of end of current month) • • • Separate Application for each month To be submitted 4 days prior to date of Scheduling Processing time – 3 days Processed on FCFS basis Application Received in a day to be processed together – same priority • Application Received after 17: 30 Hrs. - next day • Congestion Management – pro-rata

DAY-AHEAD BILATERAL TRANSACTION • • • Applications received within 3 days prior to the day of Scheduling and up to 15: 00 Hrs. of the day immediately preceding the day of scheduling shall be treated as having been received together for processing and shall have same priority. Processing only after processing of the Collective Transactions of the Power Exchange (s). Congestion Management – Pro-rata

SCHEDULING OF BILATERAL TRANSACTION IN A CONTINGENCY • • Only Buying Utility to make an Application to the Nodal RLDC. To be considered after 1500 hrs of the day immediately preceding the day of scheduling. In case of intra- day – scheduling from 6 th time block Congestion Management – Pro-rata

INCORPORATION IN DAILY SCHEDULES • • RLDCs to incorporate in Daily Schedules of the Regional Entities Average energy losses -estimated on weekly basis – – • • resolution of 0. 01 MW at each State/inter. Regional boundaries. ramp-up – • RLDCs – ISTS SLDC – intra-State TS at the time of commencement of the transaction ramp-down – at the time of termination of the transaction

REVISON OF SCHEDULE • Only in case of “Advance Scheduling” or “First-Cum-First Served basis” • minimum five (2) days notice • Transmission Charges and Operating Charges for 2 days • Margin Available – could be utilized for scheduling of other Open Access Transactions

Example: • Approved transaction : 1 st to 30 th of a month • schedule : 100 MW : 0000 -2400 (2400 MWh/ day) • Revision Request submitted on 12 th • Requested schedule : 15 th to 30 th 50 MW (1200 MWh/day) • Revised from : 15 th to 30 th • Charges : 2400 MWh/ day for 15 th &16 th 1200 MWh/day from 17 th to 30 th

CURTAILMENT IN CASE OF TRANSMISSION CONSTRAINTS • Allocation/Reallocation of ISGS power • Transmission constraint or to maintain grid security • curtailed in the manner, which in the opinion of RLDC, would relieve transmission constraints/ enhance grid security • Open Access Bilateral Transactions would generally be curtailed first followed by the Collective Transactions • Rerouting allowed without curtailment • Pro-rata refund of Transmission Charges

COMMERCIAL CONDITIONS • All Payment related to Open Access Charges – by Applicant to the Nodal RLDC – within three working days from the date of acceptance • Application Fees (as per Para 7 of Regulation) – non-refundable fee of Rupees five thousand (Rs. 5000/-) only • Transmission charges (Para 16 of Regulation) – Intra-region (Rs. 80/MWh) – Adjacent Region (Rs. 160/MWh) – More than two regions (Rs. 240/MWh) – STS charges – as specified by respective SERCs or Rs. 80/MWh • Operating charges (as per Para 17 of Regulation) – Rs. 2000/- per day each RLDCs/SLDCs involved

DEFAULT IN PAYMENT OF OPEN ACCESS CHARGES • Nodal RLDC, at its discretion – – – • • may not schedule the transaction or may cancel the scheduling of already scheduled transaction or may not entertain any Application of such Applicant in future until such time the default is cured. simple interest at the rate of 0. 04 % for each day of default from the Due Date of Payment Cheque has been dishonored – No cheque payment - next three (3) months

DISBURSAL OF PAYMENT • Reconcile the Open Access Charges – 10 th day of the current month • Transmission Charges and Operating Charges – for State System – Concerned STUs/SLDCs • For ISTS – 25% to be retained by CTU – 75% to be utilized for reduction of Transmission charges of Long Term customers • Refund due to curtailment – 15 th day of the current month

GENERAL CONDITIONS • “One- Time” information as per enclosed format • Application - through Post/fax • Any amendment/modification – fresh Application • Applications not been accorded the Acceptance – stand disposed off with suitable intimation to the concerned Applicant(s) • incomplete/vague Application – summarily rejected • The Applicant shall abide by the provisions of The Electricity Act, 2003, Indian Electricity Grid Code and CERC Regulations, as amended from time to time • Applicant shall keep each of the SLDCs/ RLDCs indemnified

IR Links – Till 2007 – 08 Name of the Link Capacity (MW) East-North Dehri-Sahupuri 220 k. V S/c 150 Sasaram HVDC back-to-back 500 Muzaffarpur-Gorakhpur 400 k. V D/c (Quad) 2000 Bihar Sharif(ER)-Balia 400 k. V D/c (Quad) 2000 Patna-Balia 400 k. V D/c (Quad) 2000 Sub-Total East-West 6650 Budhipadar-Korba 220 k. V T/c 36, 547 MW 8650 MW 450 Rourkela-Raipur 400 k. V D/c 2200 MW 1200 Sub-Total 2850 MW West-North 1650 Vindhyachal HVDC back-to-back Existing 220 k. V AC Lines 200 Gwalior-Agra 765 k. V S/c 2506 500 1500 Sub-Total 17, 159 1000 MW East-South 2200 1300 MW 1000 Existing 220 k. V AC Lines 1200 MW Gazuwaka HVDC back-to-back 200 Talcher-Kolar HVDC bipole (Enhanced) 40, 280 MW 2500 Sub-Total West-South 3700 Chandrapur HVDC back-to-back 2500 MW 39, 592 MW Existing 220 k. V AC Lines Till 2007 – 08 IR Capacity = 19, 700 MW 1000 300 Sub-Total East-North East 1300 Bongaigaon-Siliguri 400 k. V D/c 800 Birpara-Salakati 220 k. V D/c 200 Sub-Total 1000 Total 16500

ALL INDIA ATC (Figure shown are for April-2008) NORTHERN REGION ATC = 900 MW ATC = 1375 MW ATC = 1395 MW NORTHEASTERN REGION ATC = 900 MW ER WESTERN REGION EASTERN REGION ATC = 474 MW ATC =226 MW ATC = 950 MW ATC = 750 MW ATC = 800 MW SOUTHERN REGION ATC = 920 MW What Is ATC

All India basis

UI vs STOA market (All regions) 100% power market 92% long term market 5% UI market 3% STOA market

Open Access • Applications Processed (Since Beginning) > 20, 000 No. • Volume (Approved Energy) (Since Beginning) • Applications Approved > 90 BUs > 95 % – Refusal/Non-consent by SLDCs > 3 - 4% – Refusal due to system constraints < 0. 5 %

Open Access • Transactions between extreme corners of the country RGCCPP ( Kayamkulam) to PSEB Arunachal Pradesh(NER) to PSEB TNEB to J&K • Large number of Captive Generating plants used STOA and helped in enhancing the power availability in grid. Ugar Sugars (KAR) - JAIPUR (RAJASTHAN) Godavari Sugars (KAR) - MSEDCL NCS Sugar(ANDHARA) – GUVNL Indorama ( MAH) – APPCC ( ANDHRA)

Open Access • Even costly power was harnessed to meet the high demand RGCCPP ( Kayamkulam) (NAPTHA) to PSEB BSES(KERALA) (DIESEL) to NDMC (DELHI) • Diversity being gainfully utilised by Market players under STOA Delhi/TNEB Export in night ; Import during evening peak ANDHRA Export during evening peak ; Import in night • Generators PLF has also increased. Kayamkulam GPS - (From 57 % in 2006 -07 to 82 % in 2007 -08 - 82%)

Open Access- Way Ahead… • Presently CERC has allowed only Day ahead Market • At present CERC has allowed only National level operated Power exchanges. In due course if need arises Regional level operated exchanges will come. • In power exchanges, as per CERC norms the price discovery is through Double sided closed auction. • Collective transaction means a set of transactions discovered in power exchange through anonymous, simultaneous competitive bidding by buyers and sellers • For Power Exchange transactions the Nodal agency will be National Load Despatch Centre (NLDC).

Open Access- Way Ahead… • The ATC declaration is to be done by NLDC on its web site every day. • Depending on the corridor availabilities the solution is to be found out and the allowed trades will be intimated to NLDC. • If there is no congestion NLDC will accept the trades and issue the schedules to the power exchange and the same will be implemented in RLDC schedules. • In Power Exchange transactions both buyer and seller have to pay the Transmission and operating charges separately. • The transmission losses also have to be borne by the buyer and seller separately.

STOA OF KSEB(RGCCPP) - PSEB 0000 HRS – 2400 HRS 150 MW AT RGCCPP EXBUS POINT for 31 days PSEB CUSTOMER: TRADER: NR NVVNL INJECTING UTILITY HVDC BACK TO BACK AT VINDHYACHAL IN WR RGCCPP, KSEB DRAWEE UTILITY PSEB INTERVENING REGION WR WR HVDC BACK TO BACK AT BHADRWATHI IN WR INTERVENING REGIONAL LINK SR-WR LA DAILY PERIOD 150 MW RA CAPACITY APPROVED KE WR-NR INTERVENING STATE TRANSMISSION UTILITY KSEB SR 0000 -2400 HRS KAYAMKULAM RGCCPP NTPC)

STOA OF KSEB(RGCCPP) - PSEB 0000 HRS – 2400 HRS 150 MW AT RGCCPP EXBUS POINT for 31 days PSEB NR EXPORT AT RGCCPP BUS 150 MW LOSSES IN KERALA AT KERALA PERIPHERY LOSSES IN SR AT SR-WR PERIPHERY WR HVDC BACK TO BACK AT BHADRWATHI IN WR 3. 12% 144. 3 MW 4. 0% 138. 5 MW LA RA AT WR-NR PERIPHERY 0. 75% 148. 9 MW KE LOSSES IN WR HVDC BACK TO BACK AT VINDHYACHAL IN WR LOSSES IN NR PSEB RECIEVES SR 3. 0% 134. 4 MW KAYAMKULAM RGCCPP(NTPC)

STOA OF KSEB(RGCCPP) - PSEB 0000 HRS – 2400 HRS 150 MW AT RGCCPP EXBUS POINT for 31 days PSEB NR APPLICATION PROCESSING FEE HVDC BACK TO BACK AT VINDHYACHAL IN WR Rs 5000 PER TRANSACTION SCHEDULING CHARGES PER DAY 1. Rs 2000 2. Rs 2000 FOR WRLDC 3. Rs 2000 FOR NRLDC 4. Rs 2000 WR FOR SRLDC FOR KSEB HVDC BACK TO BACK AT BHADRWATHI IN WR through one or more LA 2. FOR Bilateral Wheeling RA 1. Rs 240 KE TRANSMISSION CHARGES PER MWHR SR region 3. Rs 80 FOR KSEB KAYAMKULAM RGCCPP(NTPC)

Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008) Old Regulations (06. 05. 2004 to 31. 03. 2005) Amended Regulations (w. e. f. 01. 04. 2005 to 31. 03. 2008) Total STOA Charges Paisa/Unit 15. 12 18. 5 Regulations, 2008 (w. e. f. 01. 04. 2008) Total STOA Charges Paisa/Unit 12. 2 Back