Open Access In Interstate Transmission system Principal Regulation 2008( 25th Jan’2008) Amendment Regulation 2009(20th May’2009) Order-Removal of difficulties,(28th June,2011) Order-Amendment to CTU procedure 28th Oct,2009
Markets & Evolution-Overview • Definitions • Legal provisions • Regulations 2-28 & CTU procedures • Sample calculations- STOA Losses & charges • Typical State OA procedures Contents POSOCO
Evolution of Power Market in India Capacity Market Ancillary Market PX 2008 Open Access 2004 ABT 2002-03 IEGC Feb.’2000
Merging of markets along with synchronization of regions INDIA 3,287,263 sq. km area More than 1 Billion people (2001 census) Installed Capacity of 141.08 GW (Jan-08) August 2006 North synchronized With Central Grid March 2003 West synchronized With East & Northeast NEW Grid South Grid October 1991 East and Northeast synchronized Central Grid North East West Northeast South FiveRegional Grids Five Frequencies
Present Market at a Glance Short Term Open Access Medium TermMarket Long TermMarket Bilateral Transaction Contingency Transaction Collective Transaction Day Ahead Transaction 12-25 Yr 3months -3Years After Clearance of PX 3 month ahead Day Ahead ahead On the day of operation Term ahead Schedules Balancing Market ( UI ) ( Real Time Operation )
DEFINITION OF “OPEN ACCESS” IN THE ELECTRICITY ACT, 2003 .“Open Access” means 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”. • Section 2(47) of Electricity Act 2003
LEGAL FRAMEWORK [SECTION-9(2)] • Every person, who has constructed a captive generating plant and maintains and operates such plant, shall have the right to open access for the purposes of carrying electricity from his captive generating plant to the destination of his use • Provided that such open access shall be subject to availability of adequate transmission facility and such availability of transmission facility shall be determined by the Central Transmission Utility or the State Transmission Utility, as the case may be
Legal Framework(Sections 38/39/40/42) CTU / STU/ Distribution licensee / Transmission licensee-functions & duties • To provide non-discriminatory open access to its transmission system for use by- (i) any licensee or generating company on payment of the transmission charges; or (ii) any consumer as and when such open access is provided by the State Commission under sub-section (2) of section 42, on payment of the transmission charges and a surcharge thereon, as may be specified by the Central Commission:. • CTU can not engage in generation/trading. • STU can not engage in trading • Transmission Licensee can not engage in trading
Regulation 2: Definitions • “bilateral transaction” means a transaction for exchange of energy (MWh) between a specified buyer and a specified seller, directly or through a trading licensee or discovered at power exchange through anonymous bidding, from a specified point of injection to a specified point of drawl for a fixed or varying quantum of power (MW) for any time period during a month • “collective transaction” means a set of transactions discovered in power exchange through anonymous, simultaneous competitive bidding by buyers and sellers; • “regional entity” means a person whose metering and energy accounting is done at the regional level; • “intra-State entity” means a person whose metering and energy accounting is done by the State Load Despatch Centre or by any other authorized State utility;
Regulation 2: Definitions….contd • “short-term customer” means a person who has availed or intends to avail short term open access • “short-term open access” means open access for a period up to one (1)month at one time • “regional entity” means a person whose metering and energy accounting is done at the regional level; • Short term market means a market with contracts for a period not exceeding one year from :: Power markets 2010 Regs • Short term access applications allowed upto 3 months in advance considering visibility & ATC/TTC issues.
Regulation 2: Definitions….contd • “State network” means network owned by the State Transmission Utility, distribution licensee or any other person granted licence by the State Commission to construct, operate and maintain the transmission system; • “State utility” means a State Transmission Utility, or a State Electricity Board,or Electricity Department of the State, or a State Government organization authorized to sell or purchase electricity on behalf of the State; • “time block” means 15 minutes time period specified in the Grid Code for the purposes of scheduling and despatch; and
Regulation 3: Scope • The long-term-customer and the medium-term customer shall have priority over the short-term customer for use of the inter-State transmission system. • The short-term customer shall be eligible for short-term open access over the surplus capacity available on the inter-State transmission system after use by the long-term customer and the medium-term customer, by virtue of • inherent design margins; • margins available due to variation in power flows; and • Margins available due to in-built spare transmission capacity created to cater to future load growth or generation addition.
Regulation 4: Detailed Procedure • Subject to the provisions of these regulations, the Central Transmission Utility, till the Regional Load Despatch Centre is operated by it and thereafter the Government company or any authority or corporation notified by the Central Government under subsection (2) of Section 27 of the Act: shall, after obtaining prior approval of the Commission, issue the detailed procedure to operationalise open access and on any residual matter not covered under these regulations
Regulation 5: Nodal Agency • The nodal agency for bilateral transactions shall be the Regional Load Despatch Centre of the region where point of drawal of electricity is situated and in case of the collective transactions, the nodal agency shall be the National Load Despatch Centre.
CTU PROCEDURES NODAL AGENCY • For Short-Term Customers • RLDC of the Region in which the drawal point is located. • For Long & Medium Term Customers • Central Transmission Utility (CTU), if its system is used • Transmission Licensee/ STU of the region in which the drawl point is located when CTU system is not involved.
Regulation 6: Submission of STOA Application • A short-term customer or the power exchange (on behalf of buyers and sellers) intending to avail of STOA for use of the transmission lines or associated facilities for such lines on the ISTS, shall make an application to the nodal agency • The application for a bilateral transaction shall contain the details, such as • names and location of supplier and buyer, • contracted power (MW) to be scheduled and interface at which it is referred to, • point of injection, • point of drawal, • starting time block and date, • ending time block and date, and • such other information that may be required in the detailed procedure. • The application for a collective transaction shall contain the requisite details in accordance with the detailed procedure.
GENERAL CONDITIONS/APPLICATION SUBMISSION CTU PROCEDURES • As per OA regulations Dtd. 25/01/08 w.e.f 01/04/08 & OA Amendment Regulations Dtd. 20/05/09 & as per order-amendment to CTU procedure Dtd.28/10/09 • RLDC will check if connectivity with CTU/ ISTS or STU system (as the case may be) is established, necessary metering,protection, communication are in place, transfer capability upto the CTU network for power flow of the quantum of injection/drawal applied for is available on the date of application and whether the applicant has undertaken to abide by the Central Electricity Authority (Technical Standards for Connectivity to the Grid) Regulations, 2007. • Application to be submitted to:: • Nodal RLDC where point of drawal is situated • & also to all RLDCs involved in the transaction • Application Contents • Details:: Buyer / Seller / Point of injection/ point of drawal / Contracted power at supplier interface/ date/ time period (as per (Format-I-Application for scheduling) alongwith application fee/SLDC concurrance
Regulation 7: Application Fee • An application made for each bilateral transaction or the collective transaction shall be accompanied by a non-refundable fee of Rupees five thousand (` 5000/-)only • Provided that the fee for bilateral transaction on the day of the application or on the day immediately following the day of the application may be deposited within three working days of submission of the application.
Regulation 8: Concurrence of SLDC for bilateral and collective transactions • When a Proposed bilateral transaction has a State utility or an intra-State entity as a buyer or a seller • concurrence of the SLDC shall be obtained in advance and submitted along with the application to the nodal agency in the form as in the detailed procedure. • When a State utility or an intra-State entity proposes to participate in trading through a power exchange, it shall obtain • a “no objection” or a prior standing clearance from the SLDC in the form as in the detailed procedure, specifying the MW up to which the entity may submit a buy or sell bid in a power exchange.
Regulation 8: Concurrence of SLDC for bilateral and collective transactions…..contd 3(a) For obtaining concurrence or ‘no objection’ or prior standing clearance : • Application before the SLDC • Acknowledgement receipt of the application, either by e-mail or fax, or any other recognised mode , • within twenty four hours • At the time of submission in case submitted in person 3(b) SLDC shall verify the following, namely- • existence of infrastructure necessary for time-block-wise energy metering and accounting in accordance with the provisions of the Grid Code in force, and • availability of surplus transmission capacity in the State network. 3(c) SLDC to concur ‘no objection’ / prior standing clearance • Within three (3) working days if infrastructure exists • Within seven (7) working days for a first time STOA Customer • Within two (2) working days for a defective/incomplete application
Regulation 8: Concurrence of SLDC for bilateral and collective transactions…..contd • In case of SLDCs refusal ( Application is in order) • To be communicated, within the period of three (3) working days or seven (7) working days • Reasons for such refusal: • In case of no Communication by SLDC • STOA shall be deemed to have been granted: • In case of deemed STOA grant by SLDC • the applicant while making application shall submit to the nodal agency an affidavit (in the format provided in the detailed procedure), duly notarised, declaring that – • (a) the SLDC has failed to convey any deficiency or defect in the application or its refusal or concurrence or ‘no objection’ or prior standing clearance
Regulation 8: Concurrence of SLDC for bilateral and collective transactions…..contd • (b) necessary infrastructure for time-block-wise energy metering and accounting in accordance with the provisions of the Grid Code in force, is in place; and enclosing with the affidavit – • (i) a copy of the complete application after removal of deficiency or rectification of defects, if any communicated, made to the SLDC for seeking concurrence or ‘no objection’ or prior standing clearance, as the case may be, and • (ii) a copy of the acknowledgement, if any, given by the SLDC, or any other evidence in support of delivery of the application.
CTU PROCEDURES SUBMISSION OF APPLICATION • SLDC concurrance • Concerned SLDCs concurrence in advance (Format - II-Concurrance from SLDC) • In case of deemed concurrance the applicant alongwith the application shall submit duly notarized affidavit (Format-IIA-Affidavit-Deemed concurrance from SLDC • RLDC concurrance - Bilateral Transaction having a State Utility or an intra-state Entity as a Buyer/Seller in other region:: concurrence of the concerned Regional Load Despatch Centre(s). - Nodal applications to be considered first before giving other concurrance - Reasons for refusal
CTU PROCEDURES SUBMISSION OF APPLICATION • Affidavit for deemed SLDC concurrance: • (a) the State Load Despatch Centre has failed to convey any deficiency or defect in the application or its refusal or concurrence or ‘no objection’ or prior standing clearance, as the case may be, within the specified time(3/7days) • (b) necessary infrastructure for time-block-wise energy metering and accounting in accordance with the provisions of the Grid Code in force, is in place; and enclosing with the affidavit – • (i) a copy of the complete application after removal of deficiency or rectification of defects, if any communicated for seeking concurrence or ‘no objection’ or prior standing clearance, as the case may be, and • (ii) a copy of the acknowledgement, if any, given by the State Load Despatch Centre, or any other evidence in support of delivery of the application to the State Load Despatch Centre.”
Categories & Time Line For Open Access M0 M1 M2 M3 DOP DL-10 DL-5 DL DL+5 DOP-4 Adv Application for M1 DOP-1 FCFS CONTINGENCY Adv Application for M2, Approvals for M1 Adv Application for M3, Approvals for M2 Approvals for M3 Day Ahead / PX LEGEND: DOP : Day of Operation DL : Last day of M0
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 MO – for transaction in M1, M2, M3) • Cut-off time of application: 17:30 Hrs. of last day (Day 0) • Request for concurrence (RLDC) – by 12:00 Hrs.(Day 1) (Format- III) • Concurrence - by 20:00 Hrs(Day 1) • Congestion Information to Applicant – 12:00 Hrs(Day 2)-Format-IV(Congestion information-Advance scheduling) • Revised Request/re-routing – 11:00 HRs.(Day3)-Format-V-Request for revision due to congestion) • E-bidding – in case of Congestion (Day 4) • Acceptance/Refusal of Scheduling Request – (Day5)-Format-VI-Acceptance for scheduling
Application for advance scheduling M1 M0 M2 M3 Application Separate application shall be made for each month, and for each transaction.
Time Line for Advance Scheduling M1 M0 M2 M3 10 5 5 ` Last Day for submission of Applications for transactions in M1, M2, M3 Processing time for RLDCs
Regulation 10 Congestion Management : e- Bidding Procedure • Invitation of Bids from the concerned applicant • period of congestion • RTS/IR corridor expected to get over stressed • 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 • Applicant getting approval < request Charges as quoted • Applicant getting approval=request Charges as paid by last applicant getting approval = request
Regulation 11,12,&13 Procedure for FCFS, Day ahead & Contingency bilateral transactions
“FIRST-COME-FIRST-SERVED”(FCFS) • Scope • FCFS shall be considered only when transactions are commencing & terminating in the same calender month. • Separate Application for each month • To be submitted 4 days prior to date of Scheduling • Processing time – 3 days on FCFS basis • Applications received during last 10 / 5 days of month of M0 for M1/M2 would be considered only after complete processing of Advance transactions for M1 & M2 • Application Received upto 1730 hrs in a day to be processed together – same priority • Application Received after 17:30 Hrs. - to be considered as received next day • Congestion Management – pro-rata
Application for FCFS scheduling M1 17:30 Hrs M0 M2 M3 D-04 D-03 D0 Application Processing time Separate application shall be made for each transaction.
Regulation 12: DAY-AHEAD • 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 same priority • Processing only after processing of the Collective Transactions of the Power Exchange (s) • Congestion Management – Pro-rata
Application for Day ahead scheduling M1 M0 M2 M3 D-03 D0 Application Processing time Approval after Collective Separate application for each transaction.
Regulation 13: CONTINGENCY • Buying Utility/Trader on its behalf 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/same day – scheduling from 6th time block • Congestion Management – Pro-rata
Regulation 14: Revision of Schedule • Only in case of “Advance Scheduling” or “First-Cum-First Served basis” • Accepted schedule for Day-Ahead & Contingency transaction shall not be revised or cancelled except for tripping of generators > 100MW as per Cl.6.5.19 of IEGC. • Revision w.e.f 4th time block of intimation to RLDC • Generator to furnish expected restoration time from which original schedules would become effective. • For period of revision/cancellation upto two days:: Original transmission/operating charges • For period of revision/cancellation > two days:: Transmission Charges and Operating Charges for the period beyond two (2) days shall be payable as per the revised accepted schedule and for the first two (2) days as per the original schedule. • Margin Available – released for scheduling of eligible Open Access Transactions
Regulation 15:: CURTAILMENT IN CASE OF TRANSMISSION CONSTRAINTS • Transmission constraint or to maintain grid security • Curtailed in the manner, which in the opinion of RLDC, would relieve transmission constraints/ enhance grid security • Curtailment priority :: STOA(bilat)Collective(PX)MTOALTA • In case of reallocation of GOI share leading to corridor constraints • Rerouting allowed without curtailment of existing transactions • Pro-rata refund of Transmission Charges • No revision of operating charges
Regulation 16: Transmission Charges [repealed by 19(1) of Regulations on sharing of iSTS charges-2010]
Transmission Charges …. contd • The intra-State entities shall pay the transmission charges for use of the State network as fixed by the respective State Commission in addition to the charges specifie • Provided that in case the State Commission has not determined the transmission charges, the charges for use of respective State network shall be payable at the rate of Rs.80/MWh for the electricity transmitted: • Provided further that non-fixation of the transmission charges by the State Commission for use of the State network shall not be a ground for refusal of short –term open access: • Provided also that the transmission charges payable for use of the State network shall be conveyed to the Regional Load Despatch Centre concerned who shall display these rates on its web site: • Provided also that the transmission charges payable for use of the State network shall not be revised retrospectively.
Calculation of Nodal POCs Input Network Parameters Load & Generation Data Load Flow Studies Converged Network Network Reduction Reduced Network Software for PoC Charge & Loss Computation Line wise YTC Output Nodal PoC Charges and LAF
Application of POC Transmission Charge methodology for STOA transactions • Nodal POCs zoned to form Zonal POC for each Control area • Slabbing done to fall into either high, Average or Low slab For New Grid: • High Rs. 1,00,000/Mw/month Average Rs. 85,000/MW/Month Low Rs.70,000//MW/Month • Converted to High 14paise/unit Average 12 paise/unit Low 10paise/unit • Hence STOA rates applicable are Rs.140/MWH, Rs.120/MWh, Rs.100/MWh for High, average, Low slab respectively For SR Grid : • Slab rates are Rs. 150/MWh, 130/MWh, 110/MWH for High, Average, Low slabs respectively • Total No. of combinations possible(not permutations as order does not matter) : NC2 + N = N(N+1)/2 [considering N additional cases for same POC injection/withdrawal rates] • Thus increase in total number of stamp rates for various transactions have risen from 3 to 21
Application of POC Transmission Charge methodology for STOA transactions • Transmission charges payable by Entity X injecting 100MW RTC power to Entity Y • Assume X falls in high injection slab in NEW Grid while Y fall in low withdrawal slab in SR Grid • Hence POC injection for X Rs 140/MWH • Withdrawal POC for Y Rs.110/MWh • Transmission charges payable for injection would be : = 2400MWh x 140 • Transmission charges payable for withdrawal would be: = 2400MWh X 110 • Total charges payable by Trader to Nodal RLDC: = 2400*(140+110) Rs. • STU charges would be payable in addition