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Open Access

Open Access. DEFINITION OF “OPEN ACCESS” IN THE ELECTRICITY ACT, 2003.

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Open Access

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  1. Open Access

  2. 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”

  3. 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

  4. 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

  5. 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.

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

  7. Open Access – CERC Regulations, 2008

  8. 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:

  9. Evolution of Open Access Regulations OA Regulations 2004 LTOA STOA OA Regulations 2008 OA Regulations 2010 STOA- collective LTOA STOA- bilateral Connectivity MTOA

  10. Duration of STOA,MTOA and LTA 12 years-25 years 3 months-3 years 3 months LTOA STOA MTOA

  11. CERC Open Access Regulations, 2008 Effective 01.04.2008 Amended in 01.05.2009 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 : Drawing RLDC Collective : NLDC

  12. 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

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

  14. Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008)

  15. Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008)

  16. Comparison of CERC Regulations on Short-Term Open Access (Regulation 2004, Amendment 2005 and Regulations 2008)

  17. 649.86 516.03 967.58 1795.11 233.32 919.71 447.73 270.49 313.93 433.09 434.42 339.98 460.41 359.68 859.05 1462.44 2433.39 881.49 1128.39 700.91 614.15 STOA RATES 2004, 2005 & 2009 NORTHERN REGION ER-NR NORTH-EASTERN REGION WR-NR WESTERNREGION NER-ER ER-WR EASTERN REGION SR-ER SR-WR Transmission Charges: Bilateral: Rs.80/MWh – intra- regional Rs.160/MWh – Between adjacent regions Rs240/MWh – Wheeling through one or more region Collective Transactions (Px): -Rs. 100/MWh for each point of injection and drawal SOUTHERN REGION STOA CASE

  18. Short Term charges STU charges as decided by SERCs IR link charges done away with CTU charges moved from Region specific charges to generic ones Transmission charges changed from Rs/MW/day Rs/MW/block of dayRs/MWh Power Exchange transactions necessitated Point of Connection charges

  19. Procedure for Scheduling ofOpen Access (Bilateral Transaction)

  20. 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

  21. 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

  22. 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 M0 – for transaction in M1, M2, M3) • 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. (Day3) • E-bidding – in case of Congestion (next day) (Day 4) • Acceptance/Refusal of Scheduling Request – (Day 5)

  23. Time Line for Advance, FCFS, DA and Contingency Scheduling M1 D-3 D-2 D-1 D0 M0 M2 M3 M0 5 5 1500hrs 1.5hrs Deadline for submission of DA Applications for transactions on D0 Processing time for RLDCs Last Day for submission of Applications for transactions in M1, M2, M3 Deadline for submission of Contingency Applications for transactions during D0

  24. 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

  25. “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

  26. 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

  27. 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 6th time block • Congestion Management – Pro-rata

  28. INCORPORATION IN DAILY SCHEDULES • RLDCs to incorporate in Daily Schedules of the Regional Entities • Average energy losses -estimated on weekly basis • RLDCs – ISTS • SLDC – intra-State TS • resolution of 0.01 MW at each State/inter-Regional boundaries. • ramp-up • at the time of commencement of the transaction • ramp-down • at the time of termination of the transaction

  29. Start Is the application Day ahead / Contingency Is the application (Day ahead / Same Day) or (AR/FCFS) DA Is the application is Advanced Booking Con. AR FC Transaction Processing Payment Disbursement & refund STOP Payment Calculation

  30. DA Is Application Received before 15:00 hrs Contingency No Yes Collect All Applications received till 15:00 hrs with time stamp and details. Submit all applications for Consent from concerned SLDC Check for the final consent from other SLDC.

  31. DA Is Application Received before 15:00 hrs Contingency No Yes Collect All Applications received till 15:00 hrs with time stamp and details. Submit all applications for Consent from concerned SLDC Check for the final consent from other SLDC.

  32. AR Is application received in time in respect of 1st , 2nd & 3rd month Is application within stipulated time Reject Application Yes Applications are submitted for Consent from RLDC Process as FCFS application for next month for applications made for the 1st month Check for Consent

  33. Is requested capacity available? No Applicants are informed about the congestion and allowed to reduce their requirements/re-route Yes Is requested capacity now available? No Distribute the Capacity according to the current request. Yes Bids are invited for congested element Distribute the Capacity following the bidding rules. Process application if applicant wants to surrender or Revise the schedule. Consider curtailment by SLDC Stop

  34. Bid Applications have to bid for the congested element in the multiple of Rs.10/MWh and minimum bid is Rs.10/MWh Ranking from highest bidding to lowest bidding Allot the highest bidder first (in asc order). In case of same bid by 2 or more parties, allocate on pro rata basis between those Is Margin available? If more than one person gets the full requested power No Calculate the Actual Yes Lowest price among those bidding is considered for all who got full requested power Stop

  35. FC Receive the Applications for FCFS Is Margin Available? Applications are sent for Consent from ERLDC No Send a Negative Report to the Applicant Get Consent from other ERLDC Yes Application is Approved and approval is updated. Is consent positive ? No Send a negative report to the client In Case of Curtailment, Applicant is timely intimated Schedule the Capacity as Requested on FCFS basis In case of revision in Schedule reprocess the application. Yes Stop

  36. REVISON OF SCHEDULE • Only in case of “Advance Scheduling” or “First-Cum-First Served basis” • minimum five (2) days notice (5days in 2008 Regn) • Transmission Charges and Operating Charges for 2 days (5days in 2008 Regn) • Margin Available – could be utilized for scheduling of other Open Access Transactions

  37. Example: • Say an Applicant has been scheduled for 10 days from 21st day of a month to 30th day of a month for 100 MW on round the clock basis (i.e. for 2400 MWh per day). If this Applicant, on or before 15th day of that month, submits request for revision of schedule to 50MW on round the clock basis (i.e. 1200 MWh per day), the revised schedule will get implemented from the beginning of the transactions (i.e. 21st day of the month). The Applicant shall pay the Transmission Charges for 2400 MWh per day for the period from 21st to 25th day of the month. Whereas for the period from 26th day to 30th day of the month, Transmission Charges shall be payable for 1200MWh per day. • However, if the Applicant requests for such revision on 17th day of the month, his request will be implemented from 23rd day of the month. He shall pay Transmission charges for 2400 MWh per day for 5 days i.e. from 23rd to 27th day of the month and for the remaining period he shall pay the Transmission Charges based on 1200MWh per day.

  38. 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

  39. COMMERCIAL CONDITIONS • All Payment related to Open Access ST Charges • by Applicant to the Nodal RLDC • within three working days from the date of acceptance • Energy charges to be settled among the parties • Losses adjusted in kind • 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) • Wheeling (Rs.240/MWh) • STU 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

  40. 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

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

  42. GENERAL CONDITIONS • “One- Time” information as per enclosed format • For embedded utilities : • UI rate 105% for overdrawl /under injection • & 95% for over injection under drawl • Reactive charges as per SERC • 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

  43. STOA – SUCCESS STORY Developed in consultation with all stakeholders Applications Processed (Since Beginning) > 20,000 No. Volume (Approved Energy) (Since Beginning) > 90BUs Applications Approved > 95 % Refusal/Non-consent by SLDCs > 3 - 4 % Refusal due to system constraints < 0.5 %

  44. STOA – SUCCESS STORY Robust Financial Settlement System Dispute free implementation Logistics/infrastructure -In-house Confidence Building & Dissemination of knowledge

  45. Unscheduled Inter-change (UI) Charges Any mismatch between the scheduled and the actual drawal at drawal points and scheduled and the actual injection at injection points for the intra- State entities shall be determined by the concerned State Load Despatch Centre and covered in the intra-State UI accounting scheme. Unless specified otherwise by the concerned State Commission, UI rate for intra-State entity shall be 105% (for over-drawals or under generation) and 95% (for under-drawals or over generation) of UI rate at the periphery of regional entity.

  46. STOA CHARGES COLLECTED BY RLDCS DURING THE YEAR 2007-08 All figures in Crores of Rs.

  47. Issues • Invoking of Sec 11 by state Govt. barring export from IPPs in the state • URS of ISGS under STOA (as per CERC order 11-01-10) • Among the beneficiaries • Across the regions • Revision if original beneficiary recalls

  48. Revision of STOA under forced outage of Injecting unit>100MW (as per IEGC cl. 6.4.19) • Intimate SLDC/RLDC reg. reduced availability, estimated restoration time, transaction wise revision 19. Notwithstanding anything contained in Regulation 6.5(18), in case of forced outage of a unit for a Short Term bilateral transaction, where a generator of capacity of 100 MW and above is seller, the generator shall immediately intimate the same along with the requisition for revision of schedule and estimated time of restoration of the unit, to SLDC/RLDC as the case may be. With the objective of not affecting the existing contracts, the revision of schedule shall be with the consent of the buyer till 31.07.2010. Thereafter , consent of the buyer shall not be a pre-requisite for such revision of schedule. The schedule of the generator and the buyer shall be revised, accordingly. The revised schedules shall become effective from the 4th time block, counting the time block in which the forced outage is declared to be the first one.. The RLDC shall inform the revised schedule to the seller and the buyer. The original schedule shall become effective from the estimated time of restoration of the unit. However the transmission charges as per original schedule shall continue to be paid for two days.

  49. ST charges under OA • Under going changes frequently • In CERC Regulations on “Sharing Transmission Charge and Losses” w.e.f 01.01.11, ST charges as per Point of Connection charge philosophy ie. as per the Zonal charges for Injection and Drawl of the concerned Injecting and drawing utility • Losses be adjusted in kind as per the applicable Zonal losses

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