Reg.1 Short title, extent and commencement

       (1) These Regulations may be called the Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2010.
       (2) These Regulations shall come into force from 3.5.2010.
       (3) These regulations shall supersede the Indian Electricity Grid Code, 2006 which came into effect from 1.4.2006.

Reg.2 Definitions

       (1) In these Regulations unless the context otherwise requires:
       a) Act means the Electricity Act, 2003 as amended from time to time;
       b) Ancillary Services means in relation to power system (or grid) operation, the services necessary to support the power system (or grid) operation in maintaining power quality, reliability and security of the grid, eg. active power support for load following, reactive power support, black start, etc;
       c) Automatic Voltage Regulator (AVR) means a continuously acting automatic excitation control system to control the voltage of a Generating Unit measured at the generator terminals;
       d) Available Transfer Capability (ATC) means the transfer capability of the inter-control area transmission system available for scheduling c

Part.1 GENERAL

       Authority (NCA), with a proviso that it shall be duly coordinated with the respective Regional Load Despatch Centre and the beneficiaries.
       iv) Any neighbouring country inter-connected with Indian (National) Grid shall be treated as a separate control area.
       1.4 Structure of the IEGC
       This IEGC contains the following:
       i) Part 2: Role of various Organizations and their linkages
       This Part defines the functions of the various Organizations as are relevant to IEGC.
       ii) Part 3: Planning Code for inter-State transmission
       This Part provides the guidelines to be adopted in the planning and development of bulk power transfer and

Part.2 ROLE OF VARIOUS ORGANIZATIONS AND THEIR LINKAGES

       vi) licensees;
       vii) any other person notified by the State in this behalf;
       (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 centers;
       (d) 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 of the Act, on payment of the transmission charges and a surcharge thereon, as may be specified by the State Commission.
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Part.3 PLANNING CODE FOR INTER-STATE TRANSMISSION

       This Part comprises various aspects of Planning relating to Inter-State transmission systems.
       3.1 Introduction
       i) In accordance with Section 38(2)(b) of Electricity Act, 2003, the Central Transmission Utility (CTU) shall discharge all functions of planning and co-ordination relating to inter-State transmission system in coordination with State Transmission Utility, Central Government, State Governments, Generating Companies, Regional Power Committees, Central Electricity Authority (CEA), licensees and any other person notified by the Central Government in this behalf.
       ii) In accordance with Section 38(2)(d) of Electricity Act, 2003, the Central Transmission Utility (CTU) shall inter-alia provide non-discriminatory open access to its transmission system for use by
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Part.4 CONNECTION CODE

       4.1 Introduction
       CTU, STU and Users connected to, or seeking connection to ISTS shall comply with Central Electricity Authority (Technical Standards for connectivity to the Grid) Regulations, 2007 which specifies the minimum technical and design criteria and Central Electricity Regulatory Commission (Grant of Connectivity, Long-term Access and Medium-term Open Access in inter-state Transmission and related matters) Regulations, 2009.
       4.2 Objective
       The objective of the code is as given below:
       a) To ensure the safe operation, integrity and reliability of the grid.
       b) That the basic rules for connectivity are complied with in order to treat all users in a non-discriminatory manner.
    

Part.5 OPERATING CODE

       RLDCs. The final outage plan shall be intimated to NLDC, Users, STUs, CTU, other generating stations connected to ISTS and the RLDC for implementation by 31st January of each year.
       e) The above annual outage plan shall be reviewed by RPC Secretariat on quarterly and monthly basis in coordination with all parties concerned, and adjustments made wherever found to be necessary.
       f) In case of emergency in the system, viz., loss of generation, break down of transmission line affecting the system, grid disturbances, system isolation, RLDC may conduct studies again before clearance of the planned outage.
       g) NLDC/RLDC are authorized to defer the planned outage in case of any of the following, taking into account the statutory requirements:
       i. grid disturban

Part.6 SCHEDULING AND DESPATCH CODE

       6.1 Introduction
       This Part sets out the
       a) Demarcation of responsibilities between various regional entities, SLDC, RLDC and NLDC in scheduling and despatch
       b) the procedure for scheduling and despatch
       c) the reactive power and voltage control mechanism
       d) Complementary commercial mechanisms (in the Annexure1)
       6.2 Objective
       This code deals with the procedures to be adopted for scheduling of the net injection / drawals of concerned regional entities on a day ahead basis with the modality of the flow of information between the NLDC / RLDCs / SLDCs/Power Exchange and regional entities. The procedure for submission of ca

Part.7 Miscellaneous

       (1) Nothing in these Regulations shall be deemed to limit or otherwise affect the power of the Commission to pass such orders as may be necessary for meeting the ends of justice or to prevent the abuse of the process of the Commission.
       (2) Nothing in these Regulations shall bar the Commission from adopting in conformity with the provisions of the Act, a procedure, which is at variance with any of the provisions of these Regulations including summary procedures, if the Commission, in view of the special circumstance of a matter or class of matters and for reasons to be recorded in writing, deems it necessary or expedient for so dealing with such a matter or class of matters.
       (3) Nothing in these Regulations shall bar the Commission to deal with any matter or exercise any power under the Act for which no regulations have been framed, and t

ANNEXURE.1 ANNEXURE-1

       (Refer section 6.1 (d))
       Complementary Commercial Mechanisms
       1. The beneficiaries shall pay to the respective ISGS Capacity charges corresponding to plant availability and/or Energy charges for the scheduled dispatch, in accordance with the relevant contracts /orders of CERC. The bills for these charges shall be issued by the respective ISGS to each beneficiary on monthly basis.
       2. The sum of the above two charges from all beneficiaries shall fully reimburse the ISGS for generation according to the given dispatch schedule. In case of a deviation in actual generation from the dispatch schedule, the concerned ISGS shall receive or shall pay in accordance with UI regulation of CERC. Similarly, the deviation of actual drawl by any regional entity from the net drawl schedule shall be treated as UI.

ANNEXURE.2 ANNEXURE-2

       (refer section 6.6.7(iii))
       PAYMENT FOR REACTIVE ENERGY EXCHANGES ON STATE-OWNED LINES
       Case 1: Interconnecting line owned by State-A Metering Point :
       Substation of State-B
       
       Case - 2: Interconnecting line owned by State-B Metering point Substation of State-A
       
       State-B pays to State-A for
       (i) Net VArh received from State-A while voltage is below 97%, and
       (ii) Net VArh supplied to State-A while voltage is above 103%
       Note: Net VArh and net payment may be positive or negative
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