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Largest sized hydro unit (180 MW at Chamera) in the country

Salient Features Northern Regional Power System Welcome. Session on GRID CODE. In the course on “ GRID CODE AND MERIT ORDER SCHEDULING AND DESPATCH UNDER ABT ”. Largest sized hydro unit (180 MW at Chamera) in the country. INDIAN ELECTRICITY GRID CODE (IEGC).

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Largest sized hydro unit (180 MW at Chamera) in the country

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  1. Salient Features Northern Regional Power System Welcome Session on GRID CODE In the course on “ GRID CODE AND MERIT ORDER SCHEDULING AND DESPATCH UNDER ABT ” • Largest sized hydro unit (180 MW at Chamera) in the country

  2. INDIAN ELECTRICITY GRID CODE (IEGC) Salient Features Northern Regional Power System Welcome • Largest sized hydro unit (180 MW at Chamera) in the country

  3. PRESENTATION : ORGANISATION • Need for an IEGC • Development of the present IEGC version • Indian Electricity Grid Code : Contents • IEGC : Demarcation of Resposibilities • ABT / IEGC Clauses • ABT Feedback

  4. NEED FOR AN IEGC PeriodSituation Early 1970sVertically integrated SEBs. Few problems – resolved either bilaterally or at REB level. Late 1970s- Entry of Central Generating Utilities. Early1980s Gradual increase in disputes but consensu generally emerged at REB level. Late 1980s Disputes/conflicts increased in direct proportion to number of Central Sector Power Stations. Limitations in resolving the same at REB level.

  5. NEED FOR AN IEGC PeriodSituation Early 1990s Unresolved commercial disputes resulted in need of an umpire. 1994-96 Transfer of RLDCs from CEA to POWERGRID. 1997-99 Amendments to ES Act, Constitution of CERC / SERCs, Unbundling of SEBs, possible entry of mega IPPs, IPTCs - more players, more scope for confusion.

  6. DEVELOPMENT OF IEGC Feb 1999 Special Working Group Under Shri D.P. Sinha, Member CERC Submits Its Report Indicating Modalities for Formulating IEGC. 31st Mar 99 CERC issues directives to POWERGRID for preparing IEGC and organisational arrangements for the CTU. 9th April 99 Draft IEGC submitted to CERC (Petition 1/99). Apr-May 99 Draft IEGC made public on the directions of CERC to elicit comments from all sections.

  7. DEVELOPMENT OF IEGC July 1999 Public hearings by CERC on the draft IEGC on 20th, 21st & 23rd July 1999. 30th Aug 99 Revised IEGC draft submitted by POWERGRID to CERC. 30th Oct 99&CERC’s orders on above IEGC draft (Aug. 99 22nd Nov 99Version) 7th Dec 99 IEGC draft (Aug. 99 Version) revised as per above orders and filed before CERC.

  8. DEVELOPMENT OF IEGC 21st Dec 99 Final directions of CERC on the above IEGC draft. 28th Dec 99 First version of IEGC as per above orders and circulated to all agencies & implemented w.e.from 1st Feb 2000 24th July IEGC Review Panel constitution approved 2000 by CERC 17th Nov Rules & Guidelines of IEGC Review Panel 2000 approved by CERC

  9. DEVELOPMENT OF IEGC 29th March Amendments to IEGC forwarded by 2001 Review Panel to CERC after meetings on 12th Feb & 26th March 2001 22nd Feb First review of IEGC approved by CERC 2002 based on the draft submitted by CTU based on orders dated 3rd Aug 2001 and meeting of Review Panel on 10th Dec 2001. 1st April First review of IEGC in force. 2002

  10. Indian Electricity Grid Code Chapter – 1 --- General Chapter – 2 --- Role of RLDC, REB, CTU etc. and their organisational linkages Chapter – 3 --- Planning Code for Interstate transmission Chapter – 4 --- Connection conditions Chapter – 5 --- Grant of transmission license

  11. Indian Electricity Grid Code Chapter – 6 --- Operating Code for Regional Grids Chapter – 7 --- Scheduling & Despatch Code Annex – 1 --- Complementary Commercial Mechanisms Annex – 2 --- Metering Details Chapter – 8 --- Management of IEGC

  12. CHAPTER – 1 GENERAL Objective of IEGC :- The IEGC is a Compendium of Technical Rules, covering all utilities connected to or using the Inter-state Transmission System (ISTS) and provides the following : • Documentation of the principles and procedures defining the relationship between the various users of the ISTS as well as the RLDCs & SLDCs. • Facilitates the Operation, Maintenance, Development and Planning of Economic and Reliable Regional Grid. • Facilitates beneficial trading of electricity by defining a common basis of operation of the ISTS, applicable to all the users of the ISTS.

  13. CHAPTER – 1 GENERAL Scope of IEGC :- • Applicable to all parties that connect with and/or utilise the ISTS. • DVC treated similar as STU/SEB. • BBMB Generating Stations treated as Intra-State while its Transmission System treated as ISTS.

  14. CHAPTER – 1 GENERAL Non - Compliance of IEGC :- • Persistent non - compliance of any stipulation of IEGC by Constituent / ISGS / CTU shall be reported to Member Secretary, REB. • Non – compliance of IEGC stipulations by RLDC / REB shall be reported to CEA. • MS - REB / CEA would take up the matter with the defaulting agency for terminating non - compliance. • In case of inadequate response to above efforts by MS REB/CEA, non - compliance shall be reported to CERC. • CERC after due process may order the defaulting agency for compliance. CEA/REB SHALL MAINTAIN APPROPRIATE RECORDS OF SUCH VIOLATIONS.

  15. CHAPTER – 1 GENERAL KEYWORDS / DEFINITIONS FREQUENCY VARIATION INDEX (FVI) :- A performance index representing the degree of frequency variation from the nominal value of 50 Hz, over a specified period of time. N ∑ (Fi– 50)2 i=1 N FVI = 10 X --------------- ( (Fi –50)2 /N) N i=1 where, Fi = Actual Frequency in Hz at ith time period, N = Number of measurements over the specified period of time.

  16. CHAPTER – 1 GENERAL KEYWORDS / DEFINITIONS INTER STATE GENERATING STATION (ISGS) :- A Central / Mega Power Project/ other Generating Station in which two or more than two states have a share and whose scheduling is to be coordinated by the RLDC.

  17. CHAPTER – 1 GENERAL KEYWORDS / DEFINITIONS INTER STATE TRANSMISSION SYSTEM (ISTS) :- Any system for the conveyance of energy by the means of a main transmission line from the territory of one state to another state and includes : • The conveyance of energy across the territory of an intervening state as well as conveyance within the state which is incidental to such interstate transmission of energy. • The transmission of energy within the territory of a state on a system built, owned, operated, maintained or controlled by the Central Transmission Utility (CTU) or by any person /agency under the supervision and control of a CTU.

  18. CHAPTER – 1 GENERAL KEYWORDS / DEFINITIONS STANDING COMMITTEE FOR TRANSMISSION PLANNING : A committee constituted by the CEA to discuss, review and finalise the proposals for ISTS and associated Intra-State Systems.

  19. CHAPTER – 2ROLE OF RLDC, REB, CTU ETC. AND THEIR ORGANISATIONAL LINKAGES

  20. Role of RLDCs :- (EXTRACTS FROM ‘THE ELECTRICITY ACT, 2003’) Functions of RLDC’s 28 (1) The Regional Load Despatch Centre shall be the apex body to ensure integrated operation of the power system in the concerned region. (2) The Regional Load Despatch Centre shall comply with such principles, guidelines and methodologies in respect of the wheeling and optimum scheduling and despatch of electricity as the Central Commission may specify in the Grid Code. (3) The Regional Load Despatch Centre shall - • be responsible for optimum scheduling and despatch of electricity within the region, in accordance with the contracts entered into with the licensees or the generating companies operating in the region; Continued …..

  21. Role of RLDCs (contd..) :- Functions of RLDC’s (contd..) (b) monitor grid operations; (c) keep accounts of the quantity of electricity transmitted through the regional grid; (d) exercise supervision and control over the inter-State transmission system; and (e) be responsible for carrying out real time operations for grid control and despatch of electricity within the region through secure and economic operation of the regional grid in accordance with the Grid Standards and the Grid Code. (4) The Regional Load Despatch Centre may levy and collect such fee and charges from the generating companies or licensees engaged in inter-State transmission of electricity as may be specified by the Central Commission.

  22. Role of RLDCs (contd..) :- Compliance of Directions of RLDCs 29. (1) The Regional Load Despatch Centre may give such directions and exercise such supervision and control as may be required for ensuring stabilityof grid operations and for achieving the maximum economy and efficiency in the operation of the power system in the region under its control. (2) Every licensee, generating company, generating station, substation and any other person connected with the operation of the power system shall comply with the direction issued by the Regional Load Despatch Centres under sub-section (1). (3) All directions issued by the Regional Load Despatch Centres to any transmission licensee of State transmission lines or any other licensee of the State or generating company (other than those connected to inter State transmissionsystem) or sub-station in the State shall be issued through the State Load Despatch Centre and the State Load Despatch Centres shall ensure that such directions are duly complied with the licensee or generating company or sub-station. Continued …..

  23. Role of RLDCs (contd..) :- Compliance of Directions of RLDCs (contd..) (4) The Regional Power Committee in the region may, from time to time, agree on matters concerning the stability and smooth operation of the integrated grid and economy and efficiency in the operation of the power system in that region. (5) If any dispute arises with reference to the quality of electricity or safe, secure and integrated operation of the regional grid or in relation to any direction given under sub-section (1), it shall be referred to the Central Commission for decision: Provided that pending the decision of the Central Commission, the directions of the Regional Load Despatch Centre shall be complied with by the State Load Despatch Centre or the licensee or the generating company, as the case may be. (6) If any licensee, generating company or any other person fails to comply with the directions issued under sub-section (2) or sub-section (3), he shall be liable to penalty not exceeding rupees fifteen lacs.

  24. B. Role of SLDCs :- (EXTRACTS FROM ‘THE ELECTRICITY ACT, 2003’) Functions of SLDCs 32. (1) The State Load Despatch Centre shall be the apex body to ensure integrated operation of the power system in a State. (2) The State Load Despatch Centre shall - • be responsible for optimum scheduling and despatch of electricity within a State, in accordance with the contracts entered into with the licensees or the generating companies operating in that State; (b) monitor grid operations; (c) keep accounts of the quantity of electricity transmitted through the State grid; Continued …..

  25. B. Role of SLDCs (contd..):- Functions of SLDCs (contd..) (d) exercise supervision and control over the intra-state transmission system; and (e) be responsible for carrying out real time operations for grid control and despatch of electricity within the State through secure and economic operation of the State grid in accordance with the Grid Standards and the State Grid Code. (3) The State Load Despatch Centre may levy and collect such fee and charges from the generating companies and licensees engaged in intra-State transmission of electricity as may be specified by the State Commission.

  26. B. Role of SLDCs (contd..):- Compliance of Directions of SLDCs 33. (1) The State Load Despatch Centre in a State may give such directions and exercise such supervision and control as may be required for ensuring the integrated grid operations and for achieving the maximum economy and efficiency in the operation of power system in that State. (2) Every licensee, generating company, generating station, substation and any other person connected with the operation of the power system shall comply with the direction issued by the State Load Depatch Centre under subsection (1). (3) The State Load Despatch Centre shall comply with the directions of the Regional Load Despatch Centre. Continued …..

  27. B. Role of SLDCs (contd..):- Compliance of Directions of SLDCs (contd..) (4) If any dispute arises with reference to the quality of electricity or safe, secure and integrated operation of the State grid or in relation to any direction given under sub-section (1) , it shall be referred to the State Commission for decision: Provided that pending the decision of the State Commission, the direction of the State Load Despatch Centre shall be complied with by the licensee or generating company. (5) If any licensee, generating company or any other person fails to comply with the directions issued under sub-section(1), he shall be liable to penalty not exceeding rupees five lacs.

  28. C. Role of CTU :- (EXTRACTS FROM ‘THE ELECTRICITY ACT, 2003’) Functions of CTU • to undertake transmission of electricity through inter-State transmission system; (b) to discharge all functions of planning and co-ordination relating to inter-state transmission system with - (i) State Transmission Utilities; (ii) Central Government; (iii) State Governments; (iv) generating companies; (v) Regional Power Committees; (vi) Authority; (vii) licensees; (viii) any other person notified by the Central Government in this behalf; Continued …..

  29. C. Role of CTU (contd..):- Functions of CTU (contd..) (c) to ensure development of an efficient, co-ordinated and economical system of inter-State transmission lines for smooth flow of electricity from generating stations to the load centres; (d) to provide non-discriminatory open access to its transmission system for use by- • 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:

  30. D. Role of STU :- (EXTRACTS FROM ‘THE ELECTRICITY ACT, 2003’) Functions of STUs (a) to undertake transmission of electricity through intra-State transmission system; (b) to discharge all functions of planning and co-ordination relating to intra-state transmission system with - (i) Central Transmission Utility; (ii) State Governments; (iii) generating companies; (iv) Regional Power Committees; (v) Authority; (vi) licensees; (vii) any other person notified by the State Government in this behalf; Continued …..

  31. D. Role of STU (contd..):- Functions of STUs (contd..) (c) to ensure development of an efficient, co-ordinated and economical system of intra-State transmission lines for smooth flow of electricity from a generating station to the load centres; (d) to provid non-discriminatory open access to its transmission system for use by- • 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 State Commission:

  32. E. Role of CEA :- Subject to regulations made under the ERC Act,1998 by the Central Commission in the case of RLDCs and the State Commission in case of SLDCs, any dispute with reference to the operation of the Power System including grid operation and as to whether any directions issued by RLDC under subsection 55(3) or 55(4) of the amended ES Act, 1948 (sections 29(1) and 33(1) of the Electricity Act 2003) is reasonable or not, shall be referred to the Authority for decision. Provided that pending the decision of the Authority, the directions of the RLDC or the SLDCs, as the case may be, shall be complied with.

  33. CHAPTER – 3PLANNING CODE FOR ISTS Objectives :- • Specify principles, procedures and criteria which shall be used in development of ISTS. • Promote coordination amongst all regional constituents in any development of ISTS. • Provide methodology for information exchange amongst regional constituents in planning and development of ISTS. Scope :- • Applicable to all utilities using the ISTS and involved in its development.

  34. CHAPTER – 3PLANNING CODE FOR ISTS Planning Methodology :- • CEA to develop and update perspective transmission plan (10-15 yrs) for ISTS as well as Intra - State. • CTU to develop annually Five Year Plans fitting into the above perspective plan. • System strengthening schemes to be identified additionally by CTU in consultation with CEA. • ISTS proposals to be discussed, reviewed and finalised in the meeting of the ‘Standing Committee for Transmission System Planning' constituted by CEA for each Region.

  35. CHAPTER – 3PLANNING CODE FOR ISTS Planning Methodology :- • CTU Five Year Plan to be finalised by 30th September each year comprising interalia • additional equipment such as ICTs, Capacitors, Ractors etc. • Schemes open for private investors. • Action taken and progress of schemes. • STUs should plan their system based on the CTU 5 Year Plan.

  36. CHAPTER – 3PLANNING CODE FOR ISTS Planning Criteria :- • ISTS shall be capable of withstanding and be secured against the following outages without necessitating load shedding or rescheduling of generation during steady state operation. Outage of a 132 kV D/C line or Outage of a 220 kV D/C line or Outage of a 400 kV S/C line or Outage of a single ICT Continued …..

  37. CHAPTER – 3PLANNING CODE FOR ISTS Planning Criteria :- or Outage of one pole of HVDC bipole or Outage of 765 kV S/C line • The aforesaid contingencies would be superimposed over a planned outage of another 220 kV D/C line or 400 kV S/C line in another corridor and not emanating from the same sub-station. • ISTS shall be capable of withstanding the loss of most severe single system infeed without loss of stability.

  38. CHAPTER – 3PLANNING CODE FOR ISTS Planning Criteria :- ANY ONE OF THE AFORESAID EVENTS SHALL NOT CAUSE • loss of supply • abnormal frequency on sustained basis • unacceptable high or low voltage • system instability • unacceptable overloading of ISTS elements

  39. CHAPTER – 3PLANNING CODE FOR ISTS Planning Data :- SEBs/ Utilities/ MPPs/ ISGS/ IPPs to supply standard planning data to CTU by 31st March every year in formats as approved by CERC in August 2001

  40. CHAPTER – 4CONNECTION CONDITION Connection conditions specify the minimum technical and design criteria to be complied with by CTU and any agency connected to or seeking connection to ISTS. Objectives :- • Basic rules for connections are complied with to treat all agencies in a non-discriminatory manner. • No adverse effects on the new equipment connected to ISTS, the ISTS and other agency’s system. Continued …..

  41. CHAPTER – 4CONNECTION CONDITION Objectives :- • Clear identification of ownership and responsibility for all equipment at the connection point. Scope :- Applicable to all constituents and agencies connected to and involved in developing the ISTS.

  42. CHAPTER – 4CONNECTION CONDITION For New Connections :- Connection Agreement is a must. For Existing Connections :- Agreement should be in place within one year i.e. by 01.04.2003. In case of a delay in finalising the connection conditions, constituent to approach CERC with a petition along with CTU’s recommendation/comments. Cost of modification, if any, shall be borne by concerned constituent.

  43. CHAPTER – 4CONNECTION CONDITION CONNECTION AGREEMENT WOULD INCLUDE :- • A condition requiring both parties to comply with the IEGC. • Details of connection, technical requirements and commercial arrangements. • Details of any capital expenditure arising from reinforcements required, if any. • Site Responsibility Schedule. • General philosophy, guidelines etc. on protection.

  44. CHAPTER – 4CONNECTION CONDITION RELEVANT AREAS IN CONNECTION CONDITIONS:- • ISTS parameter variations • Substation equipment • Fault Clearance Times • Generating Units and Power Stations • Reactive Power Compensation • Communication Facilities • System Recording Instruments • Responsibilities for operational safety • Procedure for site access, site operational activities and maintenance standards

  45. CHAPTER – 4CONNECTION CONDITION SCHEDULE OF ASSETS OF REGIONAL GRID:- CTU shall submit annually to CERC by 30th September each year a schedule of transmission assets which constitute the regional grid as on 31st March of that year indicating ownership on which RLDC has operational control and responsibility

  46. CHAPTER – 5GRANT OF TRANSMISSION LICENCE • Separate regulations by CERC would govern the grant of transmission license. • This chapter shall not be subject to review by the IEGC Review Panel.

  47. CHAPTER – 6OPERATIONAL CODE FOR REGIONAL GRIDS • COVERING • Operational policy •   System security aspects •   Demand estimation • Demand control •   Periodic reports •   Operational liasion • Outage planning •   Recovery procedures •   Event information

  48. CHAPTER – 6OPERATIONAL CODE FOR REGIONAL GRIDS OPERATIONAL POLICY:- • Primary objective of integrated operation is to enhance the overall operational economy and reliability of the entire network. • RLDC shall supervise overall real time operation of the regional code. •   Regional constituents shall comply with this operating code.

  49. CHAPTER – 6OPERATIONAL CODE FOR REGIONAL GRIDS OPERATIONAL POLICY:- • Detailed internal operating procedures consistent with IEGC to be developed and maintained by each RLDC. • Qualified and adequately trained personnel at all locations.

  50. CHAPTER – 6OPERATIONAL CODE FOR REGIONAL GRIDS SYSTEM SECURITY ASPECTS :- All regional constituents shall endeavor to operate their systems in synchronism with each other at all times.   Deliberate isolation of any part of the grid should be done only under a grave emergency or when specifically instructed by RLDC. In case of such isolation, synchronisation of the isolated system to be done at the earliest.

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