Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013

Q: What does Section 1 of Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013 say?

Overview (a) to undertake transmission of energy through the intra-state transmission system; (b) to discharge all functions of planning and coordination relating to intra-state transmission system with, (i) Central Transmission Utility (ii) State Governments (iii) Generating Companies (iv) Regional Power Committee (v) Authority (vi) Licensees (vii) Any other person notified by the State Government in this behalf. (c) to ensure development of an efficient, coordinated and economical system of in

Raw JSON API

3. Management of Grid Code and role of various organizations. - The Grid Code is a live document and has to be periodically reviewed by a competent panel, as and when required, in the light of experience gained. This section formulates the procedures for the same.

Section 3

4. System planning code. - This , section specifies the technical and design criteria and the procedures to be applied by the State Transmission Utility and other users for planning and development of the power system.

Section 4

5. Connectivity Conditions. - This section specifies the technical criteria and standards to be complied with by STU, transmission licensees, the generating companies, distribution licensees and other users connected or seeking connection to the transmission system.

Section 5

6. System Operation Code. - 6.1 Operation Planning and Security. - This section specifies the process by which STU has to carry out the planning of the intra-state transmission system, including interface coordination with the users, for a satisfactory grid operation and system integrity.

Section 6

6. System Operation Code.

Section 6

7. Safety. - 7.1 Cross Boundary Safety. - This section specifies the requirements for safe working practices for maintenance of equipment associated with cross-boundary operations and also the procedure to be followed when the work is carried out on electrical equipment connected to another user's system.

Section 7

8. Communication and Data Acquisition. - This section specifies the minimum requirements of communication and data acquisition facilities to be provided by each user at connection points/ interface points and cross-boundary circuits.

Section 8

9. Operational Event and Incident/Accident Reporting. - This section specifies the details of minimum requirement for the exchange of information relating to operations and/or events in the total system, including the Western Grid, which may have an operational effect.

Section 9

10. Data Registration. - This section specifies a list of all the data required by STU/ Transmission Licensee which is to be provided by the users and the data required by the users to be provided by the STU/ Transmission Licensee at the required time specified in the various sections of the Grid Code.

Section 10

11. Schedule and Despatch Code. - This section deals with the procedure to be adopted for scheduling and despatch of generation of the state generating stations and scheduling for other transactions through long-term access, medium-term and short-term open access; including complementary commercial mechanisms, on a day-ahead and intra-day basis with the process of the flow of information between the 1SGS/SGS, National Load Despatch Centre (NLDC), Regional Load Despatch Centre (RLDC), power excha

Section 11

2. Any proposed revision to the Grid Code as STU reasonably thinks necessary for achievement of the objectives referred to in the relevant paragraphs of the Transmission Licence

Section 2

3. All written representations and obj ections submitted by the users at the time of review

Section 3

1. Section 39 of the Electricity Act, 2003, outlines that the functions of the State Transmission Utility (STU) shall be:

Section 39

2. Until a government company or any authority or corporation is notified by the State Government, the State Transmission Utility shall operate the State Load Despatch Centre as per Section 31 of the Act.

Section 31

4. System Planning Code.

Section 4

1. As a general rule, the Intra State Transmission System shall be capable of withstanding and be secured against the following contingency outages

Section 1

2. The above contingencies shall be considered assuming a pre-contingency system depletion (planned outage) of another 220 kV D/C line or 400 kV S/C line in another corridor and not emanating from the same substation. The planning study would assume that all the generating units operate within their reactive capability curves and the network voltage profile are also maintained within voltage limits specified.

Section 2

1. The following minimum safety working clearance shall be maintained for the bare conductors or live parts of any apparatus in outdoor substation, excluding overhead lines of HV and EHV installation. (As per CEA notification of 20th Sept, 2010, clause no. 44(2)-(iii)):

Section 1

2. Clearance above ground of the lowest conductor (as per CEA notification of 20th Sept, 2010, clause no.58):

Section 2

3. Clearance from building of high and extra-high voltage lines (as per CEA notification of 20th Sept, 2010, clause no. 61)

Section 3

5. Connection Code.

Section 5

1. Wind generating stations connected at 66 kV and above shall be capable of supplying dynamically varying reactive power support, so as to maintain power factor within limits of 0.95 lagging to 0.95 leading. Similarly, solar generating stations have to maintain power factor within limits of 0.90 lagging to 0.90 leading.

Section 1

2. Wind generating stations and solar generating stations shall have fault ride through capability of not less than 300 milli-seconds so that grid is not destabilized due to sudden outage of generation in the event of a grid disturbance.

Section 2

3. The total harmonic distortion for voltage at the connection point shall not exceed 5% with no individual harmonic higher than 3% and the total harmonic distortion for current drawn from the transmission system at the connection point shall not exceed 8%. The above measurement of Harmonics Distortion has to be carried out every six monthly and shall be reported to STUs/ Licensees.

Section 3

1. In relation to Interconnecting Transformers between EHV / HV Transmission System and the Generator Transformer Voltage System:

Section 1

2. In relation to switchgear including circuit breakers, isolators on all circuits connected to the points of connection:

Section 2

3. Lightning arresters, technical data

Section 3

4. Communication- Details of PLCC and other communication equipment installed at Connection Point(s)/ Interface Point(s).

Section 4

20. Open circuit saturation characteristic for various terminal voltages giving the exciting current to achieve the same.

Section 20

13. Details of excitation loop in block diagrams showing transfer functions of individual elements using IEEE symbols along with set values.

Section 13

1. Peak load for Connection Point/ Interface Point as well as peak load and energy forecast for Area of Supply for each of the succeeding five years.

Section 1

1. Schematic single line diagram of Distribution System (showing distribution lines from Connection Points/ Interface Points with Transmission System 220kV/ 1 IkV, 132/11 kV, 66/22 kV & 66/ 11 kV substations, consumer bus if fed directly from Transmission System)

Section 1

2. Numbering and nomenclature of,lines and substations (identified with feeding grid substations of the Transmission System and concerned 220kV/l lkV, 132/ 1 lkV, 66/22 kV & 66/11 kV substation).

Section 2

1. Relay protection installed for all transformers and feeders along with their settings and level of coordination with other users.

Section 1

3. Substation Grounding - Each transmission substation must have a ground mat solidly connected to all metallic structures and other non-energized metallic equipment. The mat shall limit the ground potential gradients to such voltage and current levels that will not endanger the safety of people or damage equipment which are in, or immediately adjacent to, the station under normal and fault conditions. The ground mat size and type shall be based on local soil conditions and available electrical

Section 3

3. Substation Grounding

Section 3

4. Metering - Meters shall be provided as specified in the Central Electricity Authority (Installation and Operation of Meters) Regulations, 2006 as amended time to time.

Section 4

4. Metering

Section 4

5. Basic Insulation Level and Insulation Coordination - (1) Basic Insulation Level (BIL) of various items of equipment and ratings of surge arresters for generating stations, lines and substations shall be decided on the following order of priority, namely:

Section 5

5. Basic Insulation Level and Insulation Coordination

Section 5

6. Protection system and Coordination - (1) Protection system shall be designed to reliably detect faults on various abnormal conditions and provide means and location to isolate the equipment or system automatically. The protection system must be able to detect a power system faults within the protection zone. The protection system should also detect abnormal operating conditions such as equipment failures or open phase conditions.

Section 6

6. Protection system and Coordination

Section 6

7. Disturbance Recording and Event Logging Facilities - User and substation connected to the grid at a substation shall provide disturbance recording and event logging facilities. All such equipment shall be provided with time synchronization facility for global common time reference.

Section 7

7. Disturbance Recording and Event Logging Facilities

Section 7

8. Schematic Diagrams - User shall prepare single line schematic diagrams in respect of its system facility and make the same available to the GETCO (State Transmission Utility), through which his system is connected and the State Load Despatch Centre.

Section 8

8. Schematic Diagrams

Section 8

9. Inspection, Test, Calibration and Maintenance prior to connection - Before connecting, the user shall complete all inspections and tests finalized in consultation with the GETCO (State Transmission Utility) to which his equipment is connected. The user shall make available all drawings, specifications and test records of the project GETCO (State . Transmission Utility) or generating station, as the case may be.

Section 9

1. The generating companies shall install operational metering to the licensees' specifications, so as to provide operational information for both, real time and recording purposes to SLDC in relation to each generating unit, at each generating station, in respect of the following:

Section 1

2. All the instrument transformers used in conjunction with the operational metering shall be of accuracy class 0.2, except where already existing CT/PT; which are of 0.5 class, which may continue to be used. These shall be of suitable rating to meet the burden of lead wires and meters and shall conform to the relevant IEC or IS specifications.

Section 2

3. All the meters shall be calibrated to achieve the overall accuracy of Operational Metering in accordance with the limits agreed to between the Transmission Licensee/Distribution Licensee and the generating company. Records of calibration shall be maintained for reference and shall be made available to the licensee, upon request. Joint site testing shall be carried out at least once in six months.

Section 3

1. The Transmission Licensee shall install and make operative an Operational Metering Data Collection System under SCADA for storage, display and processing of operational metering data. All users shall make available outputs of their respective operational meters to the SCADA interface equipment.

Section 1

2. The data collection, storage and display centre shall be the State Load Despatch Centre (SLDC).

Section 2

1. The Generating Companies, CPP, Transmission Licensees, Distribution Licensees and EHV consumers who intend to use open access provisions would need to install the meters suitable for Availability Based Tariff (ABT) at interutility exchange points, which would record the parameters as mentioned under clause V.9.

Section 1

2. The auxiliary transformers in the generating stations shall be provided with the following meters:

Section 2

3. Each metering point associated with determination of energy exported or imported, between the generating companies, Transmission Licensees and Distribution Licensees shall be provided with both, main and check meters on separate core of CT/EMPT/CVT. The minimum standard of accuracy for these meters shall be accuracy class 0.2s. If the present metering system needs upgradation to class 0.2s, it shall be completed within six months from the effective date of this code.

Section 3

4. All the instrument transformers used in conjunction with commercial (tariff) metering shall also be of accuracy class 0.2s, except where already existing CT/EMPT/CVT/ which are of 0.5 class, shall be upgraded to class 0.2s within two years from the effective date of this code. These shall conform to the relevant IEC or IS specifications. The rating shall take into account the burdens imposed by lead wires and metering.

Section 4

5. Accuracy class: All interface meters and meters for energy accounting and audit shall be of 0.2S class of accuracy. Consumer meters shall have the following characteristics:

Section 5

6. Data shall be collected from both, the main and check metering schemes.

Section 6

7. Voltage failure relays shall be provided to initiate alarm on loss of one or more phases of the voltage supply to the meter.

Section 7

8. All the meters shall be tested and calibrated at least once in every five years, using standard meters for this purpose. The standard meters shall be calibrated and sealed at a government- authorized meter testing house/laboratory once a year. Records of testing and calibration of substandard meters shall be maintained by the Transmission Licensee according to the guidelines provided in the relevant IEC/IS specifications. Records of these calibrations and tests shall be maintained for referen

Section 8

9. In case of Inter State Transmission Lines / Intra-State Transmission lines, meters suitable for Availability Based Tariff shall be provided having the following parameters:

Section 9

10. The Generating Companies, Transmission Licensees and Distribution Licensees shall formulate a procedure, covering the summation, collection and processing of tariff meter readings at various connection sites in their areas. Whenever necessary, these procedures can be revised.

Section 10

11. The ownership, responsibility of maintenance and testing of these meters shall be as mutually agreed, between the users and the licensees.

Section 11

1. No item of electrical equipment shall be allowed to remain connected to the system, unless it is covered by the appropriate protection aimed at reliability, selectivity, speed and sensitivity. The guidelines mentioned in the manual on protection of generators, generator transformers, and 220 kV and 400 kV networks vide publication no 274 of C.B.I.P shall be kept in view. All the generating companies and Distribution Licensees shall cooperate with the Transmission Licensee(s) to ensure correct

Section 1

2. Protection settings shall not be altered, or protection bypassed and/or disconnected without consultation and agreement of all affected users. In case the protection has been bypassed and/or disconnected by agreement due to any cause, the same should be rectified and protection restored to normal conditions, as quickly as possible. If agreement has not been reached, the electrical equipment shall be isolated forthwith.

Section 2

1. The settings of protective relays starting from the generating unit up to the remote end of 66 kV / 33 kV and 11 kV lines shall be such that only the faulty section is isolated under all circumstances. The Transmission Licensee shall notify the initial settings and any subsequent changes to the users from time to time. Routine checks on the performance of the protective relays shall be conducted and any malfunction shall be noted and corrected as soon as possible. The Transmission Licensee sh

Section 1

2. The Transmission Licensee shall be responsible for arranging periodical meetings between the generating companies and Distribution Licensees to discuss coordination of protection. The Transmission Licensee shall investigate any malfunction of protection or other unsatisfactory protection issues. The concerned licensees shall take prompt action to correct any protection malfunction or issue as discussed and agreed to in these periodical meetings.

Section 2

1. From stability considerations, the maximum Fault Clearance Time for faults on any user's system directly connected to the Transmission System, or any faults on the Transmission System itself, shall be as follows:

Section 1

2. Less Fault Clearance Time than the above is preferable.

Section 2

3. Lower Fault Clearance Times for faults on a user's system may be agreed to, but only if, in the opinion of the Transmission Licensee, system conditions allow the same. At the generating stations, line faults should be cleared at the generating station end, within the critical time, to keep the generators in synchronism.

Section 3

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    "title": "Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013",
    "short_title": "Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013",
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    "act_year": 2013,
    "act_type": "STATE",
    "location": "Gujarat",
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    "description": "Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013",
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            "number": "1",
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            "number": "1",
            "title": "1. Introduction",
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            "content": "Overview\n(a) to undertake transmission of energy through the intra-state transmission system;\n(b) to discharge all functions of planning and coordination relating to intra-state transmission system with,\n(i) Central Transmission Utility\n(ii) State Governments\n(iii) Generating Companies\n(iv) Regional Power Committee\n(v) Authority\n(vi) Licensees\n(vii) Any other person notified by the State Government in this behalf.\n(c) to ensure development of an efficient, coordinated and economical system of intra-state transmission lines for smooth flow of electricity from a generating station to load centres;\n(d) to provide non-discriminatory open access to its transmission system for use by -\n(i) any licensee or generating company on payment of the transmission charges;\nOr\n(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.\n(a) 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;\n(b) Monitor the grid operations;\n(c) Keep accounts of the quantity of electricity transmitted through the state grid;\n(d) Exercise supervision and control over the intra-state transmission system;\n(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.\n(f) Further, the SLDC and licensees shall comply and ensure compliances of directions the Regional Load Despatch Centre may give from time to time in connection with the integrated grid operation of the power system or otherwise in regard to matter which affect the operation of the Inter State Transmission System.\n(g) The hydro electric generating stations of GSECL (KHPS and UFIPS) shall be treated in a very special manner for scheduling and despatch (as these plants are operated in coordination with the irrigational requirements).",
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            "number": "1",
            "title": "1. Introduction. - This section outlines the broad features of the Grid Code.",
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        },
        {
            "number": "2",
            "title": "2. Definitions. - The various terms used in the Grid Code are defined under this section.",
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        {
            "number": "3",
            "title": "3. Management of Grid Code and role of various organizations. - The Grid Code is a live document and has to be periodically reviewed by a competent panel, as and when required, in the light of experience gained. This section formulates the procedures for the same.",
            "chapter": null,
            "content": "",
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        {
            "number": "4",
            "title": "4. System planning code. - This , section specifies the technical and design criteria and the procedures to be applied by the State Transmission Utility and other users for planning and development of the power system.",
            "chapter": null,
            "content": "",
            "footnote": "",
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            "number": "5",
            "title": "5. Connectivity Conditions. - This section specifies the technical criteria and standards to be complied with by STU, transmission licensees, the generating companies, distribution licensees and other users connected or seeking connection to the transmission system.",
            "chapter": null,
            "content": "",
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        },
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            "number": "6",
            "title": "6. System Operation Code. - 6.1 Operation Planning and Security. - This section specifies the process by which STU has to carry out the planning of the intra-state transmission system, including interface coordination with the users, for a satisfactory grid operation and system integrity.",
            "chapter": null,
            "content": "",
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        },
        {
            "number": "6",
            "title": "6. System Operation Code.",
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            "content": "6.2 System Operation, Metering and Protection Code. - This section specifies the procedure to be adopted for the scheduling of despatch of the generating units to meet the demand and drawal allocations. This section also covers the management of frequency and voltages in the transmission system, the minimum requirement of protection levels and metering specifications for various components of the system.\n6.3 Monitoring of generation and drawal. - This section formulates the procedure to be followed by the State Load Despatch Centre for monitoring the generation output, active and reactive reserve capacity required for evaluation of the performance of generating stations. The monitoring of scheduled drawal is important to ensure that SLDC contributes towards improving the regional performance, by observing grid discipline.\n6.4 Contingency Planning. - This section formulates the recovery and normalisation of the power supply process to be followed by all in the event of the failure of Gujarat power grid, or the western grid, resulting in total or partial collapse of the system, causing blackouts.",
            "footnote": "",
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            "sort_order": 8
        },
        {
            "number": "7",
            "title": "7. Safety. - 7.1 Cross Boundary Safety. - This section specifies the requirements for safe working practices for maintenance of equipment associated with cross-boundary operations and also the procedure to be followed when the work is carried out on electrical equipment connected to another user's system.",
            "chapter": null,
            "content": "7.2 Safety and Line Clear Permits. - This section sets out the procedure for recording of Line Clear Permits and guidelines for ensuring safety from electrical hazards to the consumers, general public and working personnel.",
            "footnote": "",
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            "sort_order": 9
        },
        {
            "number": "8",
            "title": "8. Communication and Data Acquisition. - This section specifies the minimum requirements of communication and data acquisition facilities to be provided by each user at connection points/ interface points and cross-boundary circuits.",
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        },
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            "number": "9",
            "title": "9. Operational Event and Incident/Accident Reporting. - This section specifies the details of minimum requirement for the exchange of information relating to operations and/or events in the total system, including the Western Grid, which may have an operational effect.",
            "chapter": null,
            "content": "",
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        },
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            "number": "10",
            "title": "10. Data Registration. - This section specifies a list of all the data required by STU/ Transmission Licensee which is to be provided by the users and the data required by the users to be provided by the STU/ Transmission Licensee at the required time specified in the various sections of the Grid Code.",
            "chapter": null,
            "content": "",
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        },
        {
            "number": "11",
            "title": "11. Schedule and Despatch Code. - This section deals with the procedure to be adopted for scheduling and despatch of generation of the state generating stations and scheduling for other transactions through long-term access, medium-term and short-term open access; including complementary commercial mechanisms, on a day-ahead and intra-day basis with the process of the flow of information between the 1SGS/SGS, National Load Despatch Centre (NLDC), Regional Load Despatch Centre (RLDC), power excha",
            "chapter": null,
            "content": "Implementation and Operation of the Grid Code:\nLimitations of the Grid Code:\nConfidentiality\nProcedures to settle disputes\nCommunication between STU/Transmission Licensee and Users",
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            "number": "2",
            "title": "2. Definitions.",
            "chapter": null,
            "content": "(1) 'Act' refers to the Electricity Act, 2003 and Gujarat Electricity Industry (Reorganisation and Regulation) Act, 2003, read together.\n(2) 'Active Energy' refers to the electrical energy produced, flowing or supplied by an electric circuit during a time interval, being the integral with respect to time of the instantaneous power, measured in units of watt-hours or standard multiples thereof; i.e. 1000 Wh = 1 kWh; 1000 kWh - 1 MWh; 1000 MWh - 1 GWh; 1000 GWh - 1 TWh.\n(3) 'Active Power' refers to the product of voltage and the in-phase component of alternating current measured in units of watts and standard multiples thereof; i.e., 1000 Watts = 1 kW; 1000 kW - 1 MW; 1000 MW - 1 GW; 1000 GW = 1 TW.\n(4) 'Apparatus' refers to all the electrical apparatus like machines, fittings, accessories and appliances, in which electrical conductors are used.\n(5) 'Apparent Power' refers to the product of voltage and alternating current measured in units of volt-amperes and standard multiples thereof; i.e., 1000 VA - 1 kVA; 1000 kVA - 1 MVA.\n(6) 'ALDC' refers to the Area Load Management Centre of the Distribution Licensee concerned.\n(7) 'Area of Supply' refers to area within which a Distribution Licensee is authorised by his license to supply electricity.\n(8) 'Automatic Voltage Regulator' (AVR) refers to a continuously acting automatic excitation system to control a generating unit terminal voltage.\n(9) 'Auxiliaries' refers to all the plant and machinery required for the generating unit's functional operations that do not form part of the generating unit.\n(10) 'Auxiliary Energy Consumption' in relation to a period, refers to the quantum of energy consumed by auxiliary equipment of the generating station and shall be expressed as a percentage of the sum of gross energy generated at the generator terminals of all the Units of the generating station:\n(11) 'Availability' refers to the availability in relation to a transmission system for a given period means the time in hours during that period the transmission system is capable of transmitting electricity at its rated voltage expressed in percentage of total hours in the given period and shall be calculated as provided in GERC (Multi Year Tariff) Regulations, 2011;\n(12) 'Available Transfer Capability' (ATC) refers to the transfer capability of the inter-control area transmission system available for scheduling commercial transactions (through long term access, medium-term open access and short-term open access) in a specific direction, taking into account the network security. Mathematically, ATC is the Total Transfer Capability less Transmission Reliability Margin.\n(13) 'Backing Down' refers to reduction of generation on instructions from SLDC/WRLDC by a generating unit under abnormal conditions.\n(14) 'Black Start' refers to the procedure necessary for recovery from a total shutdown or partial shutdown without the availability of electricity from external sources.\n(15) 'Black Start Capability' refers to an ability in respect of a Black Start Station, for at least one of its generating units or CCGT units to start-up from shutdown and to energise a part of the system and be synchronized to the system upon instruction from the State Load Despatch Centre, within two hours, without any external supply.\n(16) 'Black Start Stations' refers to generating stations having Black Start Capability.\n(17) 'Beneficiary' refers to a person who has a share in an ISGS/SGS or any generating stations\n(18) 'Bilateral Transaction' refers to a transaction for exchange of energy (MWh) between a specified buyer and a specified seller, directly or through a hading licensee or through a power exchange from a specified point of injection to a specified point of drawal for a fixed or varying quantum of power (MW), for any time period during a month.\n(19) 'Bulk Consumer' refers to any consumer who avails of supply at voltage of 33 kV or above.\n(20) 'Capacitor' refers to an electrical facility provided for generation of reactive power.\n(21) 'Central Generating Station' refers to the generating stations owned by the companies owned or controlled by the Central Government.\n(22) 'Connection Agreement' refers to an agreement between STU, intra-state transmission licensee other than STU (if any) and any person setting out the terms relating to a connection to and/or use of the intra-state transmission system.\n(23) 'Captive Power Plant (CPP)' refers to a power plant set up by any person to generate electricity for his own use and includes a power plant set up by any cooperative society or association of persons for generating electricity primarily for use of members of such a cooperative society or association.\n(24) 'Caution Notice' refers to a notice conveying a warning against interference.\n(25) 'Central Transmission Utility (CTU)' refers to any government company, which the Central Government may notify under sub section (1) of section 38 of the Electricity Act, 2003.\n(26) 'Connection' refers to the electric power lines and electrical equipment used to effect a connection of a user's system to the transmission system.\n(27) 'Connection Conditions' refers to those conditions mentioned in Section 5 (Connection Conditions) which have to be fulfilled before the user's system is connected to the grid.\n(28) 'Connection Point/ Interface Point' refers to an electrical point of connection between the transmission system and the user's system.\n(29) 'Consumer' refers to any person who is supplied with electricity for his own use by a licensee or the government or by any other person engaged in the business of supplying electricity to public under the Electricity Act 2003, or any other law for the time being in force and includes any person whose premises are for the time being, connected for the purpose of receiving electricity with the works of a licensee, the government or such other person, as the case may be.\n(30) 'Control Person' refers to a person identified as having technical capability and responsibility for cross boundary safety under section 7, Cross-Boundary Safety of the Grid Code.\n(31) 'Collective Transaction' refers to a set of transactions discovered in power exchange through anonymous, simultaneous competitive bidding by buyers and sellers.\n(32) 'Commission' refers to the Gujarat Electricity Regulatory Commission.\n(33) 'Congestion' refers to a situation where the demand for transmission capacity exceeds the Available Transfer Capability.\n(34) 'Connectivity' refers to the state of getting connected to the inter-state transmission system / intra-state transmission system by a generating station, including a captive generating plant, a bulk consumer or an intra-state transmission licensee/distribution licensees.\n(35) 'Control Area' refers to an electrical system bounded by interconnections (tie lines), metering and telemetry, which controls its generation and/or load to maintain its interchange schedule with other control areas whenever required and contributes to frequency regulation of the synchronously operating system.\n(36) 'Demand' refers to the demand for an active power in MW and reactive power in MVAr of electricity, unless otherwise specified.\n(37) 'Demand Control' refers to any of the following methods of achieving a Load reduction:\n(a) Consumer Load Management initiated by users\n(b) Consumer Load Reduction by disconnection initiated by users (other than following an instruction from Load Despatch Centre)\n(c) Consumer Load Reduction instructed by the Load Despatch Centre\n(d) Automatic Under-frequency Load Disconnection\n(e) Emergency Manual Load Disconnection.\n(38) 'Despatch' refers to operational control of an integrated electricity system involving operations such as:\n(39) 'Disconnection' refers to the physical separation of users or consumers from the system.\n(40) 'Discrimination' refers to the quality where a relay or protective system is enabled to pick out and cause to be disconnected only the faulty apparatus.\n(41) 'Distribution Licensees' refers to a Licensee authorised to operate and maintain a distribution system for supplying electricity to the consumer in his area of supply.\n(42) 'Distribution System' refers to the system of wires and associated facilities between the delivery points on the transmission lines or the generating station connection and the point of connection to the installation of the consumers.\n(43) 'Demand Response' refers to reduction in electricity usage by end customers from their normal consumption pattern, manually or automatically, in response to high UI charges being incurred by the state due to over-drawal by the state at low frequency, or in response to congestion charges being incurred by the state for creating transmission congestion, or for alleviating a system contingency, for which such consumers could be given a financial incentive or lower tariff.\n(44) 'Despatch Schedule' refers to the ex-power plant net MW and MWh output of a generating station, scheduled to be exported to the grid, from time to time.\n(45) 'Drawal' refers to the import/export of electrical energy from/to the grid.\n(46) 'Drawal Schedule' refers to the summation of the station-wise ex-power plant drawal schedules from all ISGS/SGS and other stations drawl from/injection to the regional grid, consequent to other long-term access, medium-term and short-term open access transactions.\n(47) 'Disturbance Recorder' (DR) refers to a device provided to record the behaviour of the pre-selected digital and analogue values of the system parameters during an event.\n(48) 'Data Acquisition System' (DAS) refers to a system provided to record the sequence of operation in time, of the relays/equipments, as well as the measurement of pre-selected system parameters.\n(49) 'Earthing' refers to connecting the conducting parts of an equipment or machinery with the general mass of earth, in such a manner ensuring at all times an immediate discharge of energy without danger, by maintaining the same efficiency at earth's potential.\n(50) 'Earthing Device' refers to a means of providing connection between a conductor and earth being of adequate strength and capability\n(51) 'Electricity' refers to electrical energy-\n(a) generated, transmitted, supplied or traded for any purpose; or\n(b) used for any purpose except the transmission of a message;\n(52) 'Electric Line' refers to any line which is used for carrying electricity for any purpose and includes,\n(a) any support for any such line, that is to say, any structure, tower, pole or other thing in, on, by or from which any such line is, or may be, supported, carried or suspended; and\n(b) any apparatus connected to any such line for the purpose of carrying electricity;\n(53) 'Electric Plant' refers to any plant, equipment, apparatus or appliance or any part thereof used for, or connected with, the generation, transmission, distribution or supply of electricity but does not include-\n(a) an electric line; or\n(b) a meter used for ascertaining the quantity of electricity supplied to any premises; or\n(c) an electrical equipment, apparatus or appliance under the control of a consumer;\n(54) 'Exciter' refers to the source of electrical power providing the field current of a synchronous machine.\n(55) 'Entitlement' refers to a share of a beneficiary (in MW / MWh) in the installed capacity/output capability of an ISGS / SGS.\n(56) 'Entity' refers to such persons who are in the control area of SLDC and whose metering and energy accounting is done at the state level.\n(57) 'Event' refers to an unscheduled or unplanned occurrence on a grid, including faults, incidents and breakdowns.\n(58) 'Event Logging Facilities' refers to a device provided to record the chronological sequence of operations, of the relays and other equipment.\n(59) 'Ex-Power Plant' refers to net MW/MWh output of a generating station, after deducting auxiliary consumption and transformation losses.\n(60) 'Frequency' refers to the number of alternating current cycles per second (expressed in Hertz) at which the system is operating.\n(61) 'Flexible Alternating Current Transmission System' (FACTS) refers to a power electronics based system and other static equipment that provide control of one or more AC transmission system parameters to enhance controllability and increase power transfer capability.\n(62) 'Forced Outage' refers to an outage of a generating unit or transmission facility due to a fault or reasons not planned.\n(63) 'Fault Locator' (FL) refers to a device provided at the end of a transmission line to measure/ indicate the distance at which a line fault may have occurred.\n(64) 'Force Majeure' refers to any event which is beyond the control of the persons involved, which they could not foresee or with a reasonable amount of diligence, could not have foreseen or which could not be prevented and which substantially affects the performance by person such being the following including but not limited to: -\n(a) Acts of God, natural phenomena, floods, droughts, earthquakes and epidemics;\n(b) Enemy acts of any government, domestic or foreign, war declared or undeclared, hostilities, priorities, quarantines, embargoes;\n(c) Riot or civil commotion;\n(d) Grid failure not attributable to a person.\n(65) 'Grid Standards' refers to the standards specified by the authority under clause (d) of the Section 73 of the Act.\n(66) 'Generating Company' refers to any company or body corporate or association or body of individuals, whether incorporated or not, or artificial juridical person, which owns or operates or maintains a generating station.\n(67) 'Generating Station' refers to any station for generating electricity, including any building and plant with step-up transformer, switchyard, switch gear, cables or other appurtenant equipment, if any used for that purpose and the site thereof, a site intended to be used for a generating station, and any building used for housing the operating staff of a generating station, and where electricity is generated by water - power, includes penstocks, head and tail works, main and regulatory reservoirs, dams and other hydraulic works, but does not in any case include any substation.\n(68) 'Generating Unit' refers to the combination of an electric power generator and its prime mover and all of its associated equipment, which together constitutes a single generating machine.\n(69) 'Generation Schedule' refers to the despatch schedule of a generating station.\n(70) 'Generator Capability Curve' refers to a diagram, which shows the MW and MVAr capability limits within which a generating unit will be expected to operate under steady state conditions.\n(71) 'Grid' refers to high voltage backbone system of inter-connected transmission lines, substations and generating stations.\n(72) 'Grid Code' refers to Gujarat Electricity Grid Code - a document describing the procedures and the responsibilities for planning and operation of the Gujarat Grid.\n(73) 'Grid Code Review Panel' or 'Panel' refers to the panel with the functions set out in the Grid Code.\n(74) 'Governor Droop' is used in relation to the operation of the governor of a generating unit, the percentage drop in system frequency, which would cause the generating unit under restricted/free governor action to change its output from zero to full load.\n(75) 'Indian Standards' (IS) refers to those standards and specifications approved by the Bureau of Indian Standards.\n(76) 'Inter-State Generating Station' (ISGS) refers to a generating station in which, two or more states have a shares.\n(77) 'Inter-State Transmission System' (ISTS) refers to Inter-state Transmission System, which includes:\n(i) Any system for the conveyance of electricity by refers to of a main Transmission Line from the territory of one state to another State;\n(ii) The conveyance of electricity across the territory of an intervening state as well as conveyance within a state, which is incidental to such inter-state transmission of electricity;\n(iii) The transmission of electricity within the territory of a state on a system; built, owned, operated, maintained or controlled by the Central Transmission Utility;\n(78) 'Interconnecting Transformer' (ICT) refers to a transformer connecting EHV lines of different voltage systems.\n(79) 'Inter tripping' refers to the tripping of circuit-breaker(s) by commands initiated from Protection at a remote location independent of the state of local Protection; or operational inter tripping.\n(80) 'Intra-state Transmission System' refers to any system for transmission of electricity other than an Inter-State Transmission System.\n(81) 'Isolation' refers to the disconnection of EHV/ HV apparatus from the remainder of the system in which that EHV/ HV Apparatus is situated.\n(82) 'Independent Power Producer' (IPP) refers to a generating company not owned/ controlled by the Central/State Government.\n(83) 'Lean Period' refers to that period in a day when the electrical power demand is low.\n(84) 'Licence' refers to any licence granted by GERC under provisions of the relevant laws in force.\n(85) 'Licensee' refers to a person who has been granted a licence under Section 14 of the Act.\n(86) 'Load' refers to the Active, Reactive or Apparent Power as the context requires, generated, transmitted or distributed.\n(87) 'Low Voltage' or 'LV' refers to voltage not exceeding 440 volts.\n(88) 'Load Factor' refers to the ratio of the average power to the maximum demand. The load factor depends on the interval of time of the maximum demand and the period over which the average is taken.\nLoad Factor\n\t\t\t\t=\nUnits\n\t\t\t\tconsumed in a given period\nMaximum\n\t\t\t\tDemand x No. of hours in the period\n(89) 'Long-term Access' refers to the right to use the intra-state transmission system for a period exceeding 12 years but not exceeding 25 years.\n(90) 'Main Protection' refers to protection equipment or system expected to have priority in initiating either a fault clearance or an action to terminate an abnormal condition in the power system.\n(91) 'Medium-term open access' refers to the right to use the intra-State transmission system or distribution system for a period exceeding three months but not exceeding three years\n(92) 'Medium-term customer' refers to a person who has been granted medium-term open access.\n(93) 'Maximum Continuous Rating' refers to the maximum continuous output in MW at the generator terminals, guaranteed by the manufacturer at rated parameters.\n(94) 'National Grid' means the entire inter-connected electric power network of the country.\n(95) 'NLDC' refers to the centre established under sub-section (1) of Section 26 of the Act.\n(96) 'Notice to Synchronize' refers to the amount of time (expressed in minutes) that is declared by a generating company in relation to a Generator to enable it to be synchronized following the receipt of an instruction to synchronize.\n(97) 'Net Drawal Schedule' refers to the drawal schedule of an entity alter deducting the apportioned transmission losses (estimated).\n(98) 'Operating Margin' refers to aggregate available capacity of a generating station in the system on real time basis, which is over and above the operating level to the maximum capacity of the generating units limited by technical parameters for short duration.\n(99) 'Operation' refers to a scheduled or planned action, relating to the operation of a system.\n(100) 'Operational Procedures' refers to management instructions and procedures both, for the safety rules and for the local and remote operation of plant and apparatus, issued in connection with the actual operation of plant and/or apparatus at or from a connecting site.\n(101) 'Out of Synchronism' refers to the condition where a system or generating unit cannot meet the requirements to enable it to be synchronized.\n(102) 'Outage' refers to a total or partial reduction in availability due to repair and maintenance of the transmission or distribution or generation facility or defect in the Auxiliary System.\n(103) 'Overhead line' refers to an electric line which is placed above the ground and in the open air but does not include live rails of a traction system;\n(104) 'Operation Coordination Sub-committee' (OCC) refers to a sub-committee of RPC with members from all regional entities, which decide the operational aspects of the regional grid.\n(105) 'Operating Range' refers to the operating range of frequency and voltage as specified under the operating code (part- 6).\n(106) 'Power System' refers to all aspects of generation, transmission, distribution and supply of electricity and includes one or more of the following; namely:\n(a) generating stations\n(b) transmission or main transmission lines\n(c) sub-stations\n(d) tie-lines\n(e) load despatch activities\n(f) mains or distribution mains\n(g) electric supply lines\n(h) overhead lines\n(i) service lines\n(j) works\n(107) 'Protection Coordination Sub-committee' refers to a sub-committee of RPC with members from all the regional entities, which decides on the protection aspects of the regional grid.\n(108) 'Part Load' refers to the condition of a generating station which is loaded, but is not running at its declared availability.\n(109) 'Partial Shutdown' refers to a shutdown of part of the system, resulting in failure of power supply, either from external connections or from the healthy part of the system.\n(110) Teak Period5 refers to that period in the day when the electrical power demand is high.\n(111) 'Person' refers to any company or body corporate or association or body of individuals, whether incorporated or not, or artificial juridical person.\n(112) 'Planned Outage' refers to an outage of generating plant or part of the transmission system, or part of a user's system coordinated by SLDC.\n(113) Tower Factor' refers to the ratio of Active Power (kW) to Apparent Power (kVA).\n(114) 'Premises' refers to any land, building or structure.\n(115) 'Protection' refers to the schemes and apparatus for detecting abnormal conditions on a system and initiating fault clearance or actuating signals or indications.\n(116) 'Protection Apparatus' refers to a group of one or more Protection Relays and/or logic elements designated to perform a specified protection function.\n(117) Tower Exchange' refers to the power exchange which has been granted registration in accordance with CERC (Power Market Regulations), 2010, as amended from time to time.\n(118) 'Rated MW' refers to the rating plate MW output of a generating unit, being that output up to which the generating unit is designed to operate.\n(119) 'Reactive Power' refers to the product of voltage and current and the sine of the phase angle between them, measured in units of volt-amperes reactive and standard multiples thereof; i.e. 1000 VAr - lkVAr, 1000 kVAr - 1 MVAr.\n(120) 'Real Time Operation' refers to action to be taken at a given time at which information about the electricity system is made available to the Load Despatch Centre concerned.\n(121) 'Regional Power Committee' refers to committee established by resolution by the Central Government for a specified region, for facilitating the integrated operation of the power system in the region.\n(122) 'Regulating Margin' refers to the system voltage and frequency, beyond which the system should not be operated.\n(123) 'Responsible Engineer/ Operator' refers to a person nominated by a user to be responsible for system control.\n(124) 'Re-synchronization' refers to the bringing of parts of the system which have gone out of synchronism with each other, back into synchronism.\n(125) 'Regional Energy Account' (REA) refers to a regional energy account prepared on monthly basis by the RPC Secretariat for the billing and settlement of 'Capacity Charge,' 'Energy Charge and Transmission Charges.'\n(126) 'Reactor' refers to an electrical facility specifically designed to absorb Reactive Power.\n(127) 'Regional Entity' refers to such persons who are in the RLDC control area and whose metering and energy accounting is done at the regional level.\n(128) 'RPC Secretariat' refers to the Secretariat of the RPC.\n(129) 'Regional Grid' refers to the entire synchronously connected electric power network of the concerned region.\n(130) 'Regional Load Despatch Centre (RLDC)' refers to the centre established under subsection (1) of Section 27 of the Act.\n(131) 'Standing Instructions' refers to an instruction issued by SLDC to a generating company, whereby in specified circumstances, the generating company should take specified action, as though a valid despatch instruction has been issued by SLDC.\n(132) 'Start-up' refers to the action of bringing a generating unit from shut-down to synchronous speed.\n(133) 'State Transmission Utility (STU)' refers to the utility notified by the government under Sub-Section (1) of Section 39 of the Electricity Act, 2003, and whose functions have been outlined under Sub-Section (2) of Section 39 of the Electricity Act, 2003.\n(134) 'Station Transformer' refers to a transformer supplying electrical power to the auxiliaries of a generating station, which is not directly connected to a generating unit terminal.\n(135) 'Substation' refers to the station for transforming or converting electricity for the transmission or distribution thereof and includes transformers, converters, switchgears, capacitors, synchronous condensers, structures, cable and other appurtenant equipment and any buildings used for that purpose and the site thereof.\n(136) 'Supervisory Control and Data Acquisition' (SCADA) refers to the communication links and data processing systems, which provide information to enable implementation of requisite supervisory and control actions.\n(137) Supply in relation to electricity refers to the sale of electricity to a licensee or consumer;\n(138) 'Synchronized' refers to those conditions where an incoming generating unit or system is connected to the busbars of another system so that the frequencies and phase relationships of that generating unit or system as the case may be, and the system to which it is connected are identical.\n(139) 'System' refers to any Transmission and Distribution System and/or Transmission System, as the case may be.\n(140) 'State Pool Account refers to the State Pool account for (i) payments regarding Unscheduled Interchanges (UI Account) or (ii) Reactive Energy exchanges (Reactive Energy Account) (iii) Congestion Charge (iv) Renewable Regulatory fund and other charges as determined by appropriate commission time to time, as the case may be.(v) State Transmission Deviation Account and other charges as determined by appropriate Commission time to time, as the case may be.\n(141) 'State Energy Account' (SEA) refers to a state energy account prepared on monthly basis by the SLDC for the billing and settlement of Capacity Charge and Energy Charge.\n(142) 'Short-term Open Access' refers to open access for a period up to one month at a time, but not exceeding a period of six months in a calendar year.\n(143) 'Spinning Reserve' refers to a part loaded generating capacity with some reserve margin that is synchronized to the system and is ready to provide increased generation at short notice pursuant to despatch instruction or instantaneously in response to a frequency drop.\n(144) 'Share' refers to a percentage share of a beneficiary in an ISGS/SGS, either notified by the Government of India or agreed through contracts and implemented through long-term access.\n(145) 'Standing Committee for Transmission Planning' refers to a committee constituted by the CEA to discuss, review and finalise the proposals for expansion or modification in the ISTS and associated intra-state systems.\n(146) 'Static VAR Compensator' (SVC) refers to an electrical facility designed for the purpose of generating or absorbing Reactive Power.\n(147) 'Shift In-charge of SLDC, Sub-SLDC' refers to the person who is in-charge of the shift for carrying out real-time power system operations and control within the state/ jurisdiction to maintain grid discipline/ stability during the shift.\n(148) 'SLDC' refers to the State Load Despatch Centre that the Centre established under subsection (1) of Section 31 of the Act.\n(149) 'Sub-SLDC' refers to one of the three stations in Gujarat state being established under Western Region System Unified Load Despatch Scheme, having as main functions, data acquisition and transfer to SLDC; and supervisory control of load centre in their respective area.\n(150) 'Total System' refers to the Transmission System and all user systems in Gujarat.\n(151) 'Transmission Licensee' refers to a licensee authorised to establish and operate transmission lines. (A license granted under Section 14 of the Act to transmit electricity).\n(152) 'Transmission Lines' refers to all high pressure cables and overhead lines (not being an essential part of the distribution system of a licensee) transmitting electricity from a generating station to another generating station or a substation, together with any step-up and step-down transformers, switch-gear and other works necessary to and used for the control of such cables or overhead lines, and such buildings or part thereof as may be required to accommodate such transformers, switch-gear and other works.\n(153) 'Transmission System' refers to the system consisting of high pressure cables and overhead lines of the Transmission Licensee for transmission of electrical power from the generating station up to Connection Point/ Interface Point with the distribution system. This shall not include any part of the distribution system.\n(154) 'Transmit' refers to conveyance of electricity by means of transmission lines and the expression \"transmission\" shall be construed accordingly;\n(155) 'Time Block' refers to block(s) of 15 minutes each, for which special energy meters record values of specified electrical parameters with the first time block starting at 00.00 hours.\n(156) 'Total Transfer Capability' (TTC) refers to the amount of electric power that can be transferred reliably over the inter-control area transmission system under a given set of operating conditions considering the effect of occurrence of the worst credible contingency.\n(157) 'Transmission Reliability Margin' (TRM) refers to the amount of margin kept in the total transfer capability necessary to ensure that the interconnected transmission network is secure under a reasonable range of uncertainties in system conditions.\n(158) 'Technical Coordination Committee' (TCC) refers to the committee set up by RPC to coordinate the technical and commercial aspects of the operation of the regional grid.\n(159) 'Transmission Planning Criteria' refers to the policy, standards and guidelines issued by the CEA for the planning and design of the transmission system.\n(160) 'Under Frequency Relay' refers to an electrical measuring relay intended to operate when its characteristic quantity reaches the relay settings by decrease in frequency.\n(161) 'User' refers to a person such as a generating company including captive generating plant or transmission licensees (other than STU) or distributor licenses or bulk customers whose electrical plant is connected to the state grid at voltage level 33kV and above.\n(162) 'Unscheduled Interchange' (UI) refers to in a time block for a generating station or a seller means its actual generation minus its total scheduled generation for a beneficiary or buyer means its total actual drawl minus its total scheduled drawl.\n(163) 'WAMS' refers to a system comprising of Phasor Measurement Units (PMUs) and the integrated data communication system for collecting various power system including the amplitude and phase angle of the various power system parameters like voltage, power flow, frequency from multiple locations on the power system and extracts the dynamic characteristics of the system from the data easily and with a high degree of accuracy.\n(164) 'Wheeling' refers to the operation whereby the distribution system and associated facilities of a transmission licensee or distribution licensee, as the case may be, are used by another person for the conveyance of electricity on payment of charges to be determined under section 62 of the Act;\n(165) 'Works' refers to electric line, and any building, plant, machinery, apparatus and any other thing of whatever description required to transmit, distribute or supply electricity to the public and to carry into effect the objects of a licence or sanction granted under the Act or any other law for the time being in force.\nInterpretation.\n•   Words in the singular or plural term, as the case may be, shall also be deemed to include the plural or singular term, respectively;\n•   the terms include or including shall be deemed to be followed by without limitation or but not limited to regardless of whether such terms are followed by such phrases or words like 'import';\n•   References herein to the code shall be construed as a reference to this code, as amended or modified by the GERC, from time to time, in accordance with the applicable laws in force;\n•   The headings are inserted for convenience and may not be taken into account for the purpose of interpretation of this code;\n•   References to any statutes, regulations or guidelines shall be construed as including all statutory provisions consolidating, amending or replacing such statutes, regulations or guidelines, as the case may be, referred to.",
            "footnote": "",
            "is_definition": true,
            "sort_order": 14
        },
        {
            "number": "3",
            "title": "3. Management of Grid Code and Role of Various Organizations.",
            "chapter": null,
            "content": "Introduction.\nObjective.\nGrid Code Review Panel\n(a) One Chief Engineer or General Manager of Gujarat State Electricity Corporation Limited (GSECL)\n(b) One representative at senior executive level from each of the state's own Distribution Licensees; viz, PGVCL, UGVCL, DGVCL and MGVCL\n(c) One representative at senior executive level of Torrent Power Ltd-Ahmedabad (TPL-Ahmedabad)\n(d) One representative at senior executive level of Torrent Power Limited-Surat(TPL-Surat)\n(e) One representative at senior executive level from National Thermal Power Corporation Limited (NTPC)\n(f) One representative at senior executive level from Western Regional Load Despatch Centre (WRLDC)\n(g) One representative at senior executive level from Western Regional Power Committee\n(h) One representative at senior executive level from each of the generating companies other than GSECL, feeding the Gujarat Grid, feeding not less than 100 MW\n(i) One representative from all CPPs, which are in parallel operation with the Gujarat Grid on rotational basis\n(j) One representative from all the generating companies of small generating stations of less than 100 MW capacity on rotational basis (k) One member from Gujarat Energy Development Agency (GEDA)\n(l) Chief Engineer of State Load Despatch Centre (SLDC)\n(m) One representative at senior executive level from Special Economic Zone (SEZ) including KPT on rotational basis\n(n) One representative at senior executive level from Ultra Mega Power Project (UMPP) located in Gujarat\n(o) One representative at senior executive level from wind developers, having capacity of 300MW or more, on rotational basis.\n(p) One representative at senior executive level from solar developers, having capacity of 25 MW or more, on rotational basis\nThe functions of the Review Panel are as follows:\n(a) Maintenance of the Grid Code and its working under continuous scrutiny and review\n(b) Consideration of all requests for review made by any user and publication of their recommendations for changes in the Grid Code, together with reasons for such changes\n(c) Provide guidance on interpretation and implementation of the Grid Code\n(d) Examination of problems raised by any user, as well as resolution of the problems\n(e) Ensuring that the changes/modifications proposed in the Grid Code are consistent and compatible with Indian Electricity Grid Code (IEGC)\n(f) Analysis of major disturbances in the Gujarat Grid soon after their occurrence and ¦ constitution of the sub-committee to investigate the reasons thereof\nReview and Revisions",
            "footnote": "",
            "is_definition": false,
            "sort_order": 15
        },
        {
            "number": "1",
            "title": "1. Reports on the outcome of such review",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 16
        },
        {
            "number": "2",
            "title": "2. Any proposed revision to the Grid Code as STU reasonably thinks necessary for achievement of the objectives referred to in the relevant paragraphs of the Transmission Licence",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 17
        },
        {
            "number": "3",
            "title": "3. All written representations and obj ections submitted by the users at the time of review",
            "chapter": null,
            "content": "Role of Various Organizations",
            "footnote": "",
            "is_definition": false,
            "sort_order": 18
        },
        {
            "number": "39",
            "title": "1. Section 39 of the Electricity Act, 2003, outlines that the functions of the State Transmission Utility (STU) shall be:",
            "chapter": null,
            "content": "(a) To undertake transmission of electricity through the intra-state transmission system;\n(b) To discharge all functions of planning and coordination relating to intra-state transmission system with\n(i) Central Transmission Utility\n(ii) State Government\n(iii) Generating companies\n(iv) Regional Power Committees\n(v) Authority\n(vi) Licensees\n(vii) Any other person notified by the State Government in this behalf;\n(c) To ensure development of an efficient, coordinated and economical system of intra-state transmission lines for smooth flow of electricity from a generating station to the load centres\n(d) To provide non-discriminatory open access to its transmission system for use by\n(i) Any licensee or generating company on payment of the transmission charges; or\n(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.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 19
        },
        {
            "number": "31",
            "title": "2. Until a government company or any authority or corporation is notified by the State Government, the State Transmission Utility shall operate the State Load Despatch Centre as per Section 31 of the Act.",
            "chapter": null,
            "content": "(1) The State Load Despatch Centre shall be the apex body to ensure integrated operation of the power system in a State.\n(2) The State Load Despatch Centre shall -\n(a) be responsible for optimum scheduling and despatch of electricity within a state, in accordance with the contracts entered into with the licensees or generating companies operating in that state;\n(b) Monitor grid operations;\n(c) Keep accounts of the quantity of electricity transmitted through the state grid;\n(d) Exercise supervision and control over the intra-state transmission system;\n(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.\n(3) The following are contemplated as exclusive functions of SLDC:\n(a) System operation and control of the state grid covering contingency analysis and operational planning on real time basis;\n(b) Scheduling / re-scheduling of generation;\n(c) System restoration following grid disturbances;\n(d) Metering and data collection;\n(e) Compiling and furnishing data pertaining to system operation;\n(f) Operation of State UI pool account, State Reactive Energy account, State Congestion Charge Account and State Transmission Deviation Accounts and other functions as directed by the Commission.\n(g) Keep account of the quantity of electricity generated in the State\n(1) The Sub-SLDC shall assist SLDC to ensure integrated operation of the power system in a state;\n(2) The Sub-SLDC shall assist SLDC for monitoring grid operations;\n(3) The Sub-SLDC shall assist SLDC for supervision and control over the intra-state transmission system within their area.\n•  Coordination with WRLDC, CTU,STU, Transmission Licensee, State Generating Stations and Distribution Licensees for smooth and reliable grid operations\n•  Ensuring the adherence to maintain the injection / drawl as per schedule for maintaining grid stability\n•  Recording the major activities performed during the shift in the log book\n•  Approving declaration of generator and requisition of DISCOMs and revisions thereof in real time operation\n•  Permitting EHV line / equipment outages and operation thereof\n•  Preparation of various reports during the shift\n•  Reviewing demand / availability in real time, forecasting and proposing for taking machine ON / OFF bar as per system requirement and merit order\n•  Updating unit outage and ensuring real time data on web site.\n•  Monitoring real time power system key operational parameters (i.e. Voltage, Current, Power Factor, Active Power, Reactive Power etc.)\n•  During the shift in case of abnormal operation parameters, he/she has to take corrective action under intimation to his/her s/s in-charge\n•  Recording abnormalities / observed and corrective action taken in log sheet/ computer\n•  Recording abnormalities not attended immediately in defect register as mechanism to inform s/s in-charge for early rectification ® Issuance of LCP (Line Clear Permit) ensuring isolation for safety and equipments & maintenance personals\n(a) One representative at senior executive level from each Discom; viz. DGVCL, MGVCL, UGVCL, PGVCL, TPL-Ahmedabad and TPL-Surat.\n(b) One representative at senior executive level from each power station and Corporate Office of Gujarat State Electricity Corporation Limited (GSECL).\n(c) One representative at senior executive level from each IPP.\n(d) One representative at senior executive level from STU.\n(e) One representative at senior executive level from SSP.\n(f) One representative at senior executive level from UMPP / MPP connected to Gujarat network with Gujarat as control area.\n(g) One representative at senior executive level from SLDC as Member Secretary.\n(i) One representative at senior executive level from GUVNL\n(ii) One representative at senior executive level from NTPC / NPC power stations connected to Gujarat network.\n(iii)One representative at senior executive level from UMPP / MPP connected to Gujarat network with control area outside Gujarat.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 20
        },
        {
            "number": "4",
            "title": "4. System Planning Code.",
            "chapter": null,
            "content": "Introduction.\n(a) Development on a user's system already connected to the Transmission System as a user development\n(b) Introduction of a new Connection Point/ Interface Point between a user's system and the Transmission System\n(c) Need to increase the system capacity, removal of operational constraints, maintenance of security standards and meeting general increases in demand\n(d) Steady state and transient stability considerations\n(a) Time required for detailed engineering, design and construction work to be carried out. This system planning therefore enforces the time scale for exchange of information between the STU and user(s). All the concerned parties, wherever appropriate, shall have due regard to the confidentiality of such information;\n(b) Time required for obtaining all the necessary statutory approvals like notification in government gazette and leading newspapers, Power and Telecommunication Co-ordination Committee (PTCC) clearance, forest clearance, railway clearance, clearance from aviation authorities, national highways, state highways etc. and the right-of-way permissions wherever required.\nObjective.\nPerspective Plan\nPlanning Philosophy\n(i) Perspective plan formulated by CEA\n(ii) Electric Power Survey of India, published by the CEA\n(iii) Transmission Planning criteria and guidelines, issued by the CEA\n(iv) Operational feedback from SLDC\n(vi) Central Electricity Regulatory Commission (Grant of Connectivity, long-term access and medium-term open access in inter-state transmission and related matters) Regulations, 2009, Gujarat Electricity Regulation Commission (Terms and Conditions of Intra- state Open Access) Regulation, 2011\n(vii) Renewable Capacity Addition Plan issued by the Ministry of New and Renewable Energy Sources (MNRES), Govt of India, Gujarat Energy Development Association (GEDA), Govt of Gujarat.\nPlanning Criterion\nGeneral Philosophy",
            "footnote": "",
            "is_definition": false,
            "sort_order": 21
        },
        {
            "number": "1",
            "title": "1. As a general rule, the Intra State Transmission System shall be capable of withstanding and be secured against the following contingency outages",
            "chapter": null,
            "content": "(a) Without necessitating load shedding or rescheduling of generation during Steady State Operation\n•  Outage of a 132 kV D/C line\n•  Outage of a 220 kV D/C line\n•  Outage of a 400 kV S/C line\n•  Outage of a 400 kV single circuit line with fixed series capacitor (FCS)\n•  Outage of single Interconnecting Transformer\n•  Outage of one pole of HVDC bipole line, or one pole of HVDC back-to-back station or\n•  Outage of 765 kV S/C line\n(b) Without necessitating load shedding but could be with rescheduling of generation during steady state operation\n•  Outage of a 400 kV S/C line with TCSC\n•  Outage of a 400kV D/C line\n•  Outage of both pole of HVDC bipole line or both poles of HVDC back to back station\n•  Outage of a 765kV S/C line with series compensation.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 22
        },
        {
            "number": "2",
            "title": "2. The above contingencies shall be considered assuming a pre-contingency system depletion (planned outage) of another 220 kV D/C line or 400 kV S/C line in another corridor and not emanating from the same substation. The planning study would assume that all the generating units operate within their reactive capability curves and the network voltage profile are also maintained within voltage limits specified.",
            "chapter": null,
            "content": "•  Loss of supply\n•  Prolonged operation of the system frequency below and above\n•  Specified limits\n•  Unacceptable high or low voltage\n•  System instability\n•  Unacceptable overloading of system elements",
            "footnote": "",
            "is_definition": false,
            "sort_order": 23
        },
        {
            "number": "1",
            "title": "1. The following minimum safety working clearance shall be maintained for the bare conductors or live parts of any apparatus in outdoor substation, excluding overhead lines of HV and EHV installation. (As per CEA notification of 20th Sept, 2010, clause no. 44(2)-(iii)):",
            "chapter": null,
            "content": "Highest System Voltage (kV)\nHighest System Voltage (kV)\nSafety Working Clearance (in Metres)\nSafety Working Clearance (in Metres)\n12\n2.6\n36\n2.8\n72.5\n3.1\n145\n3.7\n245\n4.3\n420\n6.4\n800\n10.3",
            "footnote": "",
            "is_definition": false,
            "sort_order": 24
        },
        {
            "number": "2",
            "title": "2. Clearance above ground of the lowest conductor (as per CEA notification of 20th Sept, 2010, clause no.58):",
            "chapter": null,
            "content": "(1) No conductor of an overhead line, including service lines, erected across a street shall at any part thereof be at a height of less than\n(a)\nFor lines of voltage not exceeding 650 Volts\n5.8 metres\n(b)\nFor lines of voltage exceeding 650 Volts but not\n\t\t\t\texceeding\n33 KV 6.1 metres\n(2) No conductor of an overhead line, including service lines, erected along any street, shall at any part thereof be at a height less than\n(a)\nFor lines of voltage not exceeding 650 Volts\n5.5 metres\n(b)\nFor lines of voltage exceeding 650 Volts but not exceeding 33 KV\n5.8 metres\n(3) No conductor of an overhead line including service lines, erected elsewhere than along or across any street shall be at a height less than -\n(a)\nFor lines of voltages up to and including 1 lkV,\n\t\t\t\tif bare\n4.6 metres\n(b)\nFor lines of voltages up to and including llkV,\n\t\t\t\tif insulated\n4.0 metres\n(c)\nFor high voltage lines above llkV but not\n\t\t\t\texceeding 33KV\n5.2 metres\n(4) For lines of voltage exceeding 33KV, the clearance above ground shall not be less than 5.2 metres plus 0.3 metres for every 33,000 volts or part thereof, by which the voltage of the line exceeds 33,000 volts;",
            "footnote": "",
            "is_definition": false,
            "sort_order": 25
        },
        {
            "number": "3",
            "title": "3. Clearance from building of high and extra-high voltage lines (as per CEA notification of 20th Sept, 2010, clause no. 61)",
            "chapter": null,
            "content": "(1) Where an overhead line of voltage exceeding 650 volts passes above or adjacent to any building or part of a building, it shall have on the basis of maximum sag, a vertical clearance above the highest part of the building immediately under such line, of not less than\n(a)\nFor line of voltage exceeding 650 volts up to\n\t\t\t\tand including 33,000 Volts\n3.7 metres\n(b)\nFor lines of voltage exceeding 33 KV\n3.7 metres plus 0.3 metre for every additional\n\t\t\t\t33kV or part thereof.\n(2) The horizontal clearance between the nearest conductor and any part of such building shall, on the basis of maximum deflection due to wind pressure, be not less than-\n(a)\nFor line of voltage exceeding 650 volts up to\n\t\t\t\tand including 11,000 Volts\n1.2 metres\n(b)\nFor line of voltage exceeding 11,000 volts up to\n\t\t\t\tand including 33,000 Volts\n2.0 metres\n(c)\nFor lines of voltage exceeding 33 KV\n2.0 metres plus 0.3 metre for every additional\n\t\t\t\t33kV or part thereof\n4. [ Explanation. - for the purpose of this rule, the expression \"building\" shall be deemed to include any structure, whether permanent or temporary.] Various voltage class transmission line crossing or approaching each other.(As per CEA notification of 20th Sept,2010,Clause no. 69,(IV))\n(in metres)\nSr. No.\nSr. No.\nNominal System Voltage\nNominal System Voltage\n11-66kV\n11-66kV\n110-132kV\n110-132kV\n220kV\n220kV\n400kV\n400kV\n800kV\n800kV\n1\nLow and Medium\n2.44\n3.05\n4.58\n5.49\n7.94\n2\nll-66kV\n2.44\n3.05\n4.58\n5.49\n7.94\n3\n110-132kV\n3.05\n3.05\n4.58\n5.49\n7.94\n4\n220kV\n4.58\n4.58\n4.58\n5.49\n7.94\n5\n400kV\n5.49\n5.49\n5.49\n5.49\n7.94\n6\n800kV\n7.94\n7.94\n7.94\n7.94\n7.94\nTransmission planning for renewable energy:\n(a) 50 MW capacity through 66 kV double circuit line of ACSR Dog conductor\n(b) 70 MW capacity through 66 kV double circuit line of ACSR Panther conductor\n(c) More than 70 MW capacity through 132kV/ 220kV/400kV (based on geographical location) double circuit line\n(a) No contingency for less than 70MW capacity\n(b) N-l contingency criterion is preferable for more than 70MW on 132kV/ 220kW 400kV voltage class.\nPlanning Data Requirement:\nImplementation of Transmission Plan",
            "footnote": "",
            "is_definition": false,
            "sort_order": 26
        },
        {
            "number": "5",
            "title": "5. Connection Code.",
            "chapter": null,
            "content": "Introduction.\nObjective\n(a) To ensure the safe operation, integrity and reliability of the grid\n(b) That the basic rules for connectivity are complied with in order to treat all users in a non-discriminatory manner\n(c) Any new or modified connections, when established, shall neither suffer unacceptable effects due to its connectivity to the Gujarat Grid, nor impose unacceptable effects on the system of any other connected user or STU\n(d) Any person seeking a new connection to the grid is required to be aware, in advance, of the procedure for connectivity to the Gujarat Grid and also the standards and conditions (Copy enclosed Annexure D ) his system has to meet for being integrated into the grid.\nScope\nProcedure for connection\nConnection Agreement\nImportant Technical Requirements for Connectivity to the Grid\n(a) Reactive Power compensation and/or other facilities shall be provided by STUs, and users connected to Gujarat Grid as far as possible in the low voltage systems close to the load points, thereby avoiding the need for exchange of Reactive Power to/from Gujarat Grid and to maintain Gujarat Grid voltage within the specified range.\n(b) The person already connected to the grid shall also provide additional reactive compensation as per the quantum and time frame decided by respective RPC in consultation with RLDC. The users and STUs shall provide information to RPC and RLDC regarding the installation and healthiness of the reactive compensation equipment on regular basis. RPC shall regularly monitor the status in this regard.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 27
        },
        {
            "number": "1",
            "title": "1. Wind generating stations connected at 66 kV and above shall be capable of supplying dynamically varying reactive power support, so as to maintain power factor within limits of 0.95 lagging to 0.95 leading. Similarly, solar generating stations have to maintain power factor within limits of 0.90 lagging to 0.90 leading.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 28
        },
        {
            "number": "2",
            "title": "2. Wind generating stations and solar generating stations shall have fault ride through capability of not less than 300 milli-seconds so that grid is not destabilized due to sudden outage of generation in the event of a grid disturbance.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 29
        },
        {
            "number": "3",
            "title": "3. The total harmonic distortion for voltage at the connection point shall not exceed 5% with no individual harmonic higher than 3% and the total harmonic distortion for current drawn from the transmission system at the connection point shall not exceed 8%. The above measurement of Harmonics Distortion has to be carried out every six monthly and shall be reported to STUs/ Licensees.",
            "chapter": null,
            "content": "Schedule of Assets of State Grid\nMetering for Open Access",
            "footnote": "",
            "is_definition": false,
            "sort_order": 30
        },
        {
            "number": "6",
            "title": "6. System Operation Code",
            "chapter": null,
            "content": "Operation Planning and Security\nIntroduction.\n(a) External connections\n(b) System operation\n(c) Demand control\nDemand Estimation\n(a) Data\n(b) Methodology\n(c) Assumptions\nData Requirements\nRelease of Circuits and Generator Units included in the Outage Plan\nTransmission Outage Planning\n• Grid disturbances\n• System isolation\n• Partial blackout in a state\n• Any other event in the system that may have an adverse impact on the system security by the proposed outage\nOperating Margin\nDemand Control\nDemand Disconnection\nSystem Security\n(I) Under an emergency, and conditions in which such isolation would prevent a total grid collapse and/or would enable early restoration of power supply,\n(II) For safety to human life,\n(III) When serious damage to costly equipment is imminent and such isolation would prevent it,\n(IV) When such isolation is specifically instructed by RLDC/SLDC. Complete synchronization of the grid shall be restored as soon as the conditions permit it. The restoration process shall be supervised by RLDC, in coordination with NLDC /SLDC in accordance with operating procedures separately formulated by NLDC/RLDC.\n(a) Power System Management and Operation Standards\n(b) Supply Code\n(c) Distribution Code\n(d) Power System Safety Standards\nVoltage - (kV rms)\nVoltage - (kV rms)\nNominal\nNominal\nMaximum\nMaximum\nMinimum\nMinimum\n765\n800\n728\n400\n420\n380\n220\n245\n198\n132\n145\n122\n66\n72\n60\n33\n36\n30\n(I) SLDC/RLDC may direct a wind farm to curtail its VAr drawal/ injection in case the security of grid or safety of any equipment or personnel is endangered.\n(II) During the wind generator start-up, the wind generator shall ensure that the reactive power drawal (in-rush currents in case of induction generators) shall not affect the grid performance. For these, Data Acquisition System facility shall be provided for transfer of information to concerned SLDC and RLDC.\nSystem Operation, Metering and Protection Code\nIntroduction.\nObjective.\n(a) Laying down procedures for the function of SLDC,\n(b) Defining the responsibilities of the Transmission Licensee and other users,\n(c) Specifying the minimum standards of protection to be employed in the generating stations, substations and Transmission and Distribution Systems by the concerned agencies.\nGeneral\nSystem Operation and Despatch:\n(a) Outage Planning/scheduled rostering,\n(b) Historical data of load for the same month/day/time,\n(c) Previous day's demand,\n(d) Present weather conditions and meteorological reports,\n(e) Requirement of meeting important loads on festivals etc.\n(f) Force Majeure conditions such as. cyclones, earthquake, riots etc.,\n(g) Vacations, Sundays and other holidays,\n(h) Number and frequency of breakdowns and their recovery period.\n(a) Phasor Measurement Unit (PMU) at critical locations and to ensure complete grid observability,\n(b) Broadband communication between PMU at S/s and Phasor Data Concentrator (PDC) at SLDC,\n(c) PMU data collection, analysis and observation utility,\n(d) Advance application package like oscillation stability, transient stability, voltage stability and dynamic State Estimator to observe dynamic behaviour of the system.\nMetering and Protection:\nMonitoring of Generation and Drawal\nIntroduction.\nObjective.\nMonitoring Procedure\nMonitoring of Drawal by the Grid\nGenerating Unit Trippings\nData Requirements\n(a) Generating Companies:\n(i) Quarter-hourly generation and summation on real time basis,\n(ii) Logged readings of generating units as required,\n(iii) Detailed report of the generator unit trippings.\n(b) CPPs (above 5 MW): Quarter hourly export/import MW on real time basis.\nContingency Planning\nIntroduction.\nObjective.\n(a) The essential loads to be restored immediately,\n(b) The capabilities of the generating stations,\n(c) The possible transfer of power from the neighbouring systems through Inter State Transmission Lines,\n(d) The extent of immediate availability of power from the Central Sector Generating Stations.\n(a) Restoration of the total system and associated demand in the shortest possible time\n(b) Resynchronisation of parts of the system which have ceased to be in synchronism,\n(c) To ensure that the communication arrangements for use in circumstances of serious disruption to the system, are available to enable senior management representatives of the SLDC, the Transmission Licensee and the users who are authorised to take decisions on behalf of the Transmission Licensee or the user,\n(d) To ensure that the Transmission System can operate in the event the SLDC is incapacitated for any reason.\nStrategy\nTotal Regional Blackout\nTotal and Partial State Transmission System Blackout\nResponsibilities\nSpecial Considerations",
            "footnote": "",
            "is_definition": false,
            "sort_order": 31
        },
        {
            "number": "7",
            "title": "7. Safety.",
            "chapter": null,
            "content": "Cross Boundary Safety\nIntroduction.\nObjective.\nControl Persons and their Responsibility\nProcedure\nSpecial Considerations\nSafety and Line Clear Permits\nIntroduction.\nObjective.\nSafety Standards\nLine Clear Permits (LCP)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 32
        },
        {
            "number": "8",
            "title": "8. Communication and Data Acquisition.",
            "chapter": null,
            "content": "Introduction.\nObjective.\nSupervisory Control and Data Acquisition (SCADA)\nCommunication\nData Acquisition\n(a) MW and MVAr generated or absorbed in each generating station,\n(b) MVAr imported or exported from the external connections,\n(c) Voltages in all the system busbars,\n(d) Frequency in the system,\n(e) MW & MVAr flow in each Transmission element.\n(f) Weather Data Viz. Temperature, Wind Speed & Direction, Humidity etc.\n(g) Tap position of Transformer, Breaker/ Isolator status points.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 33
        },
        {
            "number": "9",
            "title": "9. Operational Event and Incident/Accident Reporting.",
            "chapter": null,
            "content": "Introduction.\n(a) The Gujarat power grid in case of an operation and/or event occurring on a user system,\n(b) A user system in the case of an operation and/or event occurring in the Transmission System.\nObjective.\nReportable Incidents\n(a) Exceptionally high/low voltage or frequency,\n(b) Serious equipment problem; i.e. major circuit breaker, transformer, busbar fault,\n(c) Major problem in the generating unit,\n(d) Tripping of ICT, Transmission Line or Capacitor Bank,\n(e) Major fire incident, cyclones, storms, earthquakes etc.\n(f) Major protection failure,\n(g) Overloading of equipment or transmission line which may result in hazard to the personnel,\n(h) Activation of any alarm or indication of abnormal operating condition,\n(i) Adverse climatic conditions being experienced or forecast,\n(j) Breakdown, or faults, or temporary changes in the capabilities of plant and/or apparatus,\n(k) Impending risks of protection operation,\n(1) Loss of load,\n(m)Accidents,\n(n) Excessive drawal deviations,\n(o) Minor equipment alarms.\nReporting Procedure\n(a) Location of the incident,\n(b) Date and time of the incident,\n(c) Plant or equipment involved,\n(d) Supplies interrupted and the duration wherever applicable,\n(e) Amount of generation lost, wherever applicable,\n(f) System parameters before and after the incident, (voltage, frequency, flows, generation etc.)\n(g) Network configuration before the incident,\n(h) Relay indications and performance of protection,\n(i) Brief description of the incident,\n(j) Estimated time of return to service,\n(k) Any other relevant information,\n(1) Recommendations for future improvement,\n(m)Name and designation of reporting officer.\n(a) Tripping of plant and/or apparatus manually or automatically,\n(b) Voltage outside statutory limits,\n(c) System frequency outside statutory limits,\n(d) System instability,\n(e) System overloads.\nWarnings\nLoss of communication with SLDC\nMajor Failure\nAccident Reporting\nPerformance/ Operational Reporting",
            "footnote": "",
            "is_definition": false,
            "sort_order": 34
        },
        {
            "number": "10",
            "title": "10. Data Registration.",
            "chapter": null,
            "content": "Introduction.\nObjective.\nResponsibility\nList of Data to be Registered\n(a) Planning Data Requirements: Generation - As per Annexure B\n(b) Operation Planning data pertaining to the generating stations - As per Annexure E\n(c) System Data pertaining to the generating stations - As per Transmission Section 3 of GERC (Power System Management Standards) Regulations, 2005.\n(a) Planning Data Requirements: Distribution - As per Annexure B\n(b) Operation Planning Data pertaining to Distribution - As per Annexe E\nMethods of Submission of Data\nChanges in User's Data\nData not supplied\nSpecial Considerations",
            "footnote": "",
            "is_definition": false,
            "sort_order": 35
        },
        {
            "number": "11",
            "title": "11. Schedule and Despatch Code.",
            "chapter": null,
            "content": "Introduction.\n(a) Demarcation of responsibilities between various intra-state entities and SLDC in scheduling and despatch,\n(b) The procedure for scheduling and despatch,\n(c) The Reactive power and voltage control mechanism.\nObjective.\nScope\nDemarcation of Responsibilities:\nScheduling and Despatch Procedure\na. NLDC shall indicate to the Power Exchange(s), the list of interfaces/control areas/regional transmission systems on which unconstrained flows are required to be advised by the Power Exchange(s) to NLDC. The Power Exchange(s) shall furnish the interchange on various interfaces/control areas/regional transmission systems as intimated by NLDC. The Power Exchange(s) shall also furnish the information of total drawal and injection in each of the regions. Based on the information furnished by the Power Exchange(s), NLDC shall check for congestion. In case of congestion, NLDC shall inform the exchanges about the period of congestion and the available limit for scheduling of collective transaction on respective interface/control area/transmission systems during the period of congestion for scheduling of collective transaction through the respective Power Exchange. The limit for scheduling of collective transaction for the respective Power Exchange shall be worked out in accordance with CERC directives. Based on the application for scheduling of collective transaction submitted by the Power Exchange(s), NLDC shall send the details (Scheduling Request of Collective Transaction) to different RLDCs for final checking and incorporating them in their schedules. After getting confirmation from RLDCs, NLDC shall convey the acceptance of scheduling of collective transaction to the Power Exchange(s). RLDCs shall schedule the collective transaction at the respective periphery of the regional entities.\nb. The individual transactions for state utilities/intra-state entities shall be scheduled by the respective SLDCs. The Power Exchange(s) shall send the detailed break-up of each point of injection and each point of drawal within the state to respective SLDCs after receipt of acceptance from NLDC. The Power Exchange(s) shall ensure necessary coordination with SLDCs for scheduling of the transactions.\nc. The timeline for the above activities will be as per the detailed procedure for scheduling of the collective transaction issued in accordance with CERC (Open-access in inter-state transmission) Regulations, 2008 and as amended from time to time.\n(i) the ex-power plant despatch schedule to each of the generating stations, in MW for different time blocks, for the next day. The summation of the ex-power plant drawal schedules advised by all beneficiaries shall constitute the ex-power plant station-wise despatch schedule.\n(ii) the net drawal schedule to each intra-state entity, in MW, for a different time block, for the next day. The summation of the station- wise ex-power plant drawl schedule for all generating station and ISGS/SGS and drawl schedules consequent to bilateral inter changes, after deducting the transmission losses(estimated) shall constitute the entity-wise drawl schedule.\n(i) Scheduling of wind power generation plant would have to be done for the purpose of UI where the sum of generation capacity of such plants connected at the connection point to the transmission or distribution system is 10 MW and above and where PPA has not been signed before 3rd May, 2010. For capacity and voltage level below this, as well as for old wind farms (a wind farm is a collection of wind turbine generators that are connected to a common connection point), it could be mutually decided between the wind generator and the transmission and distribution utility, as the case may be, if there is no existing contractual agreement to the contrary. The schedule by wind power generating stations (excluding collective transactions) may be revised by giving advance notice to SLDC/RLDC, as the case may be. Such revisions by wind power generating stations shall be effective from 6th time block, the first being the time-block in which notice was given. There may be one revision for each time slot of 3 hours starting from 00:00 hours of a particular day subject to maximum of 8 revisions during the day.\n(ii) The schedule of solar generation shall be given by the generator, based on availability of the generator, weather forecasting, solar insulation, season and normal solar generation curve and shall be vetted by the SLDC in which the generator is located and incorporated in the 'nter-state schedule. If SLDC is of the opinion that the schedule is not realistic, it may ask the solar generator to modify the schedule.\n(iii) The SLDC shall maintain the record of the schedule from renewable power generating stations, based on the type of renewable energy sources; i.e. wind or solar from the point of view of grid security. While scheduling generating stations in a region, the system operator shall aim at utilizing available wind and solar energy fully.\nReactive Power and Voltage Control\n(a) The beneficiary pays for VAr drawal when voltage at the metering point is below 97%,\n(b) The beneficiary gets paid for VAr return when voltage is below 97%,\n(c) The beneficiary gets paid for VAr drawal when voltage is above 103%,\n(d) The beneficiary pays for VAr return when voltage is above 103%.\n(i) The two concerned beneficiaries may mutually agree not to have any charge/payment for VAr exchanges between them on an interconnecting line,\n(ii) The two concerned beneficiaries may mutually agree to adopt a payment rate/scheme for VAr exchanges between them identical to or at variance from that specified by GERC for VAr exchanges with the state transmission system. If the agreed scheme requires any additional metering, the same shall be arranged by the concerned beneficiaries,\n(iii) The computation and payments for such VAr exchanges shall be effected as mutually agreed between the two beneficiaries.\nComplementary Commercial Mechanisms\n(i) ascertaining that no component of the power system of any other constituent shall be overstressed by such interchange/trade,\n(ii) incorporating the agreed interchange/trade in the net interchange schedules for the concerned constituents.\nAnnexure A\nAnnexure A\nTransmission System Planning and Security Standard Clause (4.14)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 36
        },
        {
            "number": "1",
            "title": "1. Introduction.",
            "chapter": null,
            "content": "(a) System studies\n(b) Assessment of system data\n(c) Assessment of generation availability\n(d) Planning criteria\n(e) Security conditions required for maintaining specified degree of reliability\n(f) Criteria for substation planning\n(g) Estimation of Reactive Power compensation required",
            "footnote": "",
            "is_definition": false,
            "sort_order": 37
        },
        {
            "number": "2",
            "title": "2. Transmission Planning",
            "chapter": null,
            "content": "II. The transmission planning should be developed to achieve a strong coordinated power system for the western region and ultimately a national grid, where substantial interregional transfers can be achieved with optimised utilisation of available generation. The transmission planning shall also provide a high standard of supply to beneficiaries with acceptable degree of reliability and at reasonable cost. The criterion should be that even under the conditions of the specified outages considered in the security standards, the power flow should not be affected. The transmission planning should keep in view the long-term future load growth also and the transmission lines and substations shall be so planned that the same can be upgraded when necessary in future, with minimum interruptions and modifications.\nIII. For the purpose of reducing inventory, procurement time and installation time, the licensee shall adopt standardised designs as far as possible for transmission line towers, structures for substations, substation lighting, control room lighting and ventilation, substation earthing, standardised specification for line materials, transformers, substation equipment, cables, busbar accessories, insulators, hard wares, lightening arrestors etc.\nIV. The possibility of providing adequate transmission connections within the Gujarat state grid, as well as between inter-state grids has to be considered wherever economically feasible, considering all economic energy/capacity interchanges subject to trade-off between new generation and cost of transmission. The modem Flexible AC Transmission System (FACTS) based on thyristor-based controls, HVDC, fast controllable phase shifters etc. have also to be considered wherever economically feasible and/or constraints of corridor exist for construction of new transmission lines.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 38
        },
        {
            "number": "3",
            "title": "3. System Studies",
            "chapter": null,
            "content": "(a) Load flow\n(b) Optimal power flow for various conditions\n(c) Short circuit\n(d) System stability-steady state\n(e) System stability-transient\n(f) Studies to determine switching/temporary over voltages\n(g) Other studies as required\nII. These studies require suitable computer programmes. Mathematical models of generation, transmission and load shall be prepared separately for each year of a plan period assessing probable year of commissioning of particular lines, substations, additional transformers in existing substations etc. based on the system network for the year in question with all the generation and load buses properly located. Interconnections with the western grid through neighbouring states at 400kV and 220kV levels shall have to be incorporated. Appropriate equivalent circuit models shall be used to take into account the fault level at the Connection Points/ Interface Points. The interconnection buses shall be modelled by representing significant and necessary portions of the neighbouring networks to represent realistically the MW and MVA imports/exports. Studies shall be carried out both, for peak load and minimum load conditions.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 39
        },
        {
            "number": "4",
            "title": "4. System Data",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 40
        },
        {
            "number": "5",
            "title": "5. Generation",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 41
        },
        {
            "number": "6",
            "title": "6. Planning Criteria",
            "chapter": null,
            "content": "II. The transmission shall be planned in such a way to maintain steady state voltage within limits as stated below:\nNominal system\nNominal system\nMaximum\nMaximum\nMinimum\nMinimum\nVoltage kV-rms.\nkV- rms\nkV- rms\n66\n72\n60\n132\n145\n122\n220\n245\n198\n400\n420\n380\n765\n800\n728\n± 500kV HVDC\nIII. Line Loading Limits\nIV. Options for Strengthening of Transmission Network:\n(a) Addition of new transmission lines to avoid overloading of existing system (wherever three or more circuits of the same voltage class are envisaged between two substations, the next higher transmission voltage may be considered);\n(b) Upgradation of the existing transmission lines such as raising height of conductor supports and / or switch over to insulated cross-arms to facilitate change over to higher voltage, if the tower design so permits;\n(c) Reconductoring of the existing transmission line with higher size of conductors or with AAAC (All Aluminium Alloy Conductor);\n(d) The choice shall be based on cost, reliability, right of way requirements, energy losses, down time etc.\nV. All single circuit lines shall be planned with double circuit towers, wherever technically feasible, to enable future expansion without right-of-way problems.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 42
        },
        {
            "number": "7",
            "title": "7. Security Standards",
            "chapter": null,
            "content": "I. Steady State Stability\n(a) Outage of any tower in a D/C transmission line\n(b) Two circuits of 66 kV or 132 kV or 220 kV lines\n(c) One circuit of 400 kV line\n(d) One interconnecting transformer\n(e) One largest capacity generator\n(f) One inter-connecting line with neighbouring grid\nII. Transient Stability\n(a) Outage of the largest size generator in the western grid or connection with neighbouring grids\n(b) (i) A single line to ground fault on a 400 kV line, single pole opening of the faulted phase (5 cycles) with unsuccessful reclosure (dead time 1 sec) followed by 3 pole opening (5 cycles) of the faulted line.\n(ii) 400 kV D/C line:\ni. When both the circuits are in operation, the system shall be capable of withstanding a permanent fault on one of the circuits followed by a three-pole opening (100-m sec.) of the faulted circuit.\nii. When one of the circuits is under maintenance / outage the system shall be capable of withstanding a transient fault on the circuit in service.\n(c) A permanent 3-phase fault with duration of 8-cycles on 220 kV or 132 kV or 66 kV line, assuming three-pole opening.\n(d) No stability studies for faults are required for radial lines.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 43
        },
        {
            "number": "8",
            "title": "8. Substation Planning Criteria",
            "chapter": null,
            "content": "Voltage Level (A)\nVoltage Level (A)\nTransformer Capacity\nTransformer Capacity\nExisting Capacity (B)\nExisting Capacity (B)\nMaximum Capacity (C)\nMaximum Capacity (C)\n765 kV\n6000 MVA\n9000 MVA\n400 kV\n1260 MVA\n2000 MVA\n220 kV\n320 MVA\n500 MVA\n132 kV\n150 MVA\n250 MVA\n66 kV\n50 MVA\n75 MVA\n(a) Size and number of Interconnecting Transformers (ICTs) shall be planned in such a way that the outage of any single unit would not overload the remaining ICTs or the underlying system.\n(b) Size and number of HT / EHT transformers shall be planned in such a way that in the event of outage of any single unit, the remaining HT / EHT transformers would still supply 80% of the load. This has to be achieved in such a way that with the connection of the adjacent substations, the load exceeding the capacity of the available transformers may be transferred on to them.\n(c) The rated rupturing capacity of the circuit breaker to be installed at any new substation or switchyard shall be at least 20% higher than the calculated maximum fault level at the bus to take care of the increase in short circuit levels as the system grows. The rated breaking current capability of switchgear and breakers to be installed at different voltage levels, based on available capacities of the breakers, shall be considered as shown in table below [CEA Manual on Transmission Planning Criteria-jan-2013];\n66 kV\n25 KA/ 31.50 KA\n132 kV\n25 KA/ 31.50 KA\n220 kV\n31.5 KA/40 KA\n400 kV\n50KA/63 KA\n765 kV\n40 KA/50KA",
            "footnote": "",
            "is_definition": false,
            "sort_order": 44
        },
        {
            "number": "9",
            "title": "9. Reactive Compensation",
            "chapter": null,
            "content": "I. Shunt Capacitors - Shunt capacitor shall be installed at 22 kV and 11 kV preferably at load centres. In case it is not possible at the load centre, then reactive compensation shall be provided in 66/132 kV systems, with a view to meet the reactive power requirement of load close to the load points.\nII. Shunt Reactors - Switchable shunt reactors shall be provided at 400 kV sub-stations for controlling voltages within the limits specified. The step changes shall not cause a voltage variation exceeding 5%. Suitable line reactors (switchable/fixed) shall be provided to enable charging of 400 kV lines without exceeding voltage limits specified. The line reactors shall be installed for long line at high voltage level for curtailing switching over voltage and limiting the fault currents.\nAnnexure-B\nAnnexure-B\nPlanning Data Requirement from the Generating and Distribution Company (Clause 4.24, Clause 10.4,10.5)\nPart-1 - Generation\n(To be furnished by the generating company to STU)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 45
        },
        {
            "number": "1",
            "title": "1. Standard Planning Data (Generation)",
            "chapter": null,
            "content": "1.1 Thermal\n1.1 Thermal\n(I) General:\n1.\nSite\nFurnish location map (schematic) showing roads,\n\t\t\t\trailway lines, transmission lines, rivers, and reservoirs, if\n\t\t\t\tany.\n2.\nApproximate period of construction\n3.\nAnnual generation in million kWH\n(II) Connection:\n1.\nConnection Point / Interface Point Furnish\n\t\t\t\tsingle line diagram of the proposed connection with the\n\t\t\t\tTransmission System with clear indication of possibility for\n\t\t\t\tright-of-way for unobstructed outlet\n2.\nStep up voltage for connection kV\n(III) Station Capacity:\n1\nTotal generating station capacity (MW)\n2\nNo. of units and unit size MW\nState whether development will be carried out in\n\t\t\t\tphases and if so, furnish details\n(IV) Generating Unit Data:\n1.\nGenerator\n(a) Make and Type\n(b) Rating (MVA)\n(c) Terminal Voltage\n\t\t\t\t(kV)\n(d) Rated Power\n\t\t\t\tFactor\n(e) Reactive Power\n\t\t\t\tcapability (MVAr) in the range 0.95 leading and 0.85 lagging\n(f) Short Circuit\n\t\t\t\tRatio\n(g) Direct axis\n\t\t\t\ttransient reactance (% on MVA rating)\n(h) Direct axis\n\t\t\t\tsub-transient reactance (% on MVA rating)\n(i) Auxiliary Power Requirement\n2.\nGenerator Transformer\n(a) Type\n(b) Rated Capacity\n\t\t\t\t(MVA)\n(c) Voltage Ratio\n\t\t\t\t(HV/LV)\n(d) Tap change range\n\t\t\t\t(+ % to - %)\n(e) Percentage Impedance (Positive Sequence at\n\t\t\t\tFull load).\n1.2 Hydro Electric\n1.2 Hydro Electric\n(i) General:\n(as applicable to thermal generating stations mentioned above)\n(ii) Connection:\n(as applicable to thermal generating stations mentioned above)\n(iii) Station Capacity\n(as applicable to thermal generating stations mentioned above)\n(iv) Generation Unit Data:\n(as applicable to thermal generating stations mentioned above)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 46
        },
        {
            "number": "2",
            "title": "2. Detailed Planning Data (Generation)",
            "chapter": null,
            "content": "2.1 Thermal Generating Stations\n2.1 Thermal Generating Stations\nI. General:\nI. General:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 47
        },
        {
            "number": "1",
            "title": "1. Name of generating station",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 48
        },
        {
            "number": "2",
            "title": "2. No. and capacity of generating units (MW)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 49
        },
        {
            "number": "3",
            "title": "3. Single line diagram of generating station and switchyard",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 50
        },
        {
            "number": "4",
            "title": "4. Relaying and metering diagram",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 51
        },
        {
            "number": "5",
            "title": "5. Neutral grounding of generating units",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 52
        },
        {
            "number": "6",
            "title": "6. Excitation control",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 53
        },
        {
            "number": "7",
            "title": "7. Earthing arrangements with earth resistance values",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 54
        },
        {
            "number": "8",
            "title": "8. Communication- details of PLCC and other communication equipment installed",
            "chapter": null,
            "content": "II. Protection and Metering:\nII. Protection and Metering:\n1 Full description including settings for all relays and protection systems installed on the generating unit, generating unit transformer, auxiliary transformer and electrical motor of major equipment; viz. boiler feed pump, ID fans, condensate extraction pump etc.\n2 Full description including settings for all relays installed on all outgoing feeders from generating station switchyard, tie circuit breakers, incoming circuit breakers.\n3 Full description of inter-tripping of circuit breakers at Connection Point(s) / Interface Point(s) with the Transmission System\n4 Most probable fault clearance time for electrical faults on the user's system\n5 Full description of operational and commercial metering schemes\n6 Breaker operating time counting from initiation of protective relay to the opening of breaker\nIII. Switchyard:\nIII. Switchyard:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 55
        },
        {
            "number": "1",
            "title": "1. In relation to Interconnecting Transformers between EHV / HV Transmission System and the Generator Transformer Voltage System:",
            "chapter": null,
            "content": "(a) Rated MVA\n(b) Voltage Ratio\n(c) Vector Group\n(d) Positive sequence reactance (maximum, minimum, normal Tap (% on MVA)\n(e) Positive sequence resistance (maximum, minimum, normal Tap (% on MVA)\n(f) Zero sequence reactance (% on MVA)\n(g) Tap changer range (+ % to - %) and steps\n(h) Type of tap changer (OFF/ON)\n(i) Details of reactors, and other circuits connected to tertiary winding of ICT\n(j) Method of grounding",
            "footnote": "",
            "is_definition": false,
            "sort_order": 56
        },
        {
            "number": "2",
            "title": "2. In relation to switchgear including circuit breakers, isolators on all circuits connected to the points of connection:",
            "chapter": null,
            "content": "(a) Rated voltage (kV)\n(b) Type of breaker (MOCB/ABCB/SF6 ---)\n(c) Rated short circuit breaking current (kA) 3 Phase\n(d) Rated short circuit breaking current (kA) 1 Phase\n(e) Rated short circuit making current (kA) 3 Phase\n(f) Rated short circuit making current (kA) 1 Phase\n(g) Provisions of auto re-closing with details.\n(h) Details of instrument transformers",
            "footnote": "",
            "is_definition": false,
            "sort_order": 57
        },
        {
            "number": "3",
            "title": "3. Lightning arresters, technical data",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 58
        },
        {
            "number": "4",
            "title": "4. Communication- Details of PLCC and other communication equipment installed at Connection Point(s)/ Interface Point(s).",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 59
        },
        {
            "number": "5",
            "title": "5. Basic insulation level (kV)",
            "chapter": null,
            "content": "(a) Busbar\n(b) Switchgear\n(c) Transformer bushings\n(d) Transformer windings\nIV Generating Units:\nIV Generating Units:\nA. Parameters of Generating Units:\nA. Parameters of Generating Units:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 60
        },
        {
            "number": "1",
            "title": "1. Rated terminal voltage (kV)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 61
        },
        {
            "number": "2",
            "title": "2. Rated MVA",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 62
        },
        {
            "number": "3",
            "title": "3. Rated MW",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 63
        },
        {
            "number": "4",
            "title": "4. Inertia constant H (MW Sec./MVA) of generator",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 64
        },
        {
            "number": "5",
            "title": "5. Short circuit ratio",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 65
        },
        {
            "number": "6",
            "title": "6. Direct axis synchronous reactance (% on MVA) (Both unsaturated and saturated)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 66
        },
        {
            "number": "7",
            "title": "7. Direct axis transient reactance (% on MVA) (Both unsaturated and saturated)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 67
        },
        {
            "number": "8",
            "title": "8. Direct axis sub-transient reactance (% on MVA) (Both unsaturated and saturated)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 68
        },
        {
            "number": "9",
            "title": "9. Quadrature axis synchronous reactance (% on MVA) (Both unsaturated and saturated)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 69
        },
        {
            "number": "10",
            "title": "10. Quadrature axis transient reactance (% on MVA) (Both unsaturated and saturated)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 70
        },
        {
            "number": "11",
            "title": "11. Quadrature axis sub-transient reactance (% on MVA) (Both unsaturated and saturated)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 71
        },
        {
            "number": "12",
            "title": "12. Direct axis transient open circuit time constant (Sec) T' do",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 72
        },
        {
            "number": "13",
            "title": "13. Direct axis sub-transient open circuit time constant (Sec) Tdo",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 73
        },
        {
            "number": "14",
            "title": "14. Quadrature axis transient open circuit time constant (Sec) T' qo",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 74
        },
        {
            "number": "15",
            "title": "15. Quadrature axis sub-transient open circuit time constant (Sec) Tqo",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 75
        },
        {
            "number": "16",
            "title": "16. Stator resistance (Ohm)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 76
        },
        {
            "number": "17",
            "title": "17. Stator leakage reactance (Ohm) Ta",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 77
        },
        {
            "number": "18",
            "title": "18. Stator time constant (Sec)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 78
        },
        {
            "number": "19",
            "title": "19. Rated field current (A)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 79
        },
        {
            "number": "20",
            "title": "20. Open circuit saturation characteristic for various terminal voltages giving the exciting current to achieve the same.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 80
        },
        {
            "number": "21",
            "title": "21. Generator Capability Curve",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 81
        },
        {
            "number": "22",
            "title": "22. Rated stator current (A)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 82
        },
        {
            "number": "23",
            "title": "23. Phase connection",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 83
        },
        {
            "number": "24",
            "title": "24. Number of terminals brought out",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 84
        },
        {
            "number": "25",
            "title": "25. Rated speed (rpm)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 85
        },
        {
            "number": "26",
            "title": "26. Rated Frequency (Hz.)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 86
        },
        {
            "number": "27",
            "title": "27. Efficiency at MCR condition (percent)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 87
        },
        {
            "number": "28",
            "title": "28. Negative sequence current capability (I2T)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 88
        },
        {
            "number": "29",
            "title": "29. Capacitance of generator stator winding to ground (microf/ph)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 89
        },
        {
            "number": "30",
            "title": "30. DC resistance of rotor at 200 C (in ohm)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 90
        },
        {
            "number": "31",
            "title": "31. Zero sequence reactance X0 (Percentage)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 91
        },
        {
            "number": "32",
            "title": "32. Negative sequence reactance X2 (Percentage)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 92
        },
        {
            "number": "33",
            "title": "33. Negative sequence reactance R2 (Percentage)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 93
        },
        {
            "number": "34",
            "title": "34. Sub-Transient S-C time constant (in second)",
            "chapter": null,
            "content": "a. Direct axis Td\nb. Quadrature axis Tq",
            "footnote": "",
            "is_definition": false,
            "sort_order": 94
        },
        {
            "number": "35",
            "title": "35. Transient S-C time constant (in second)",
            "chapter": null,
            "content": "a. Direct axis T'd\nb. Quadrature axis T'q",
            "footnote": "",
            "is_definition": false,
            "sort_order": 95
        },
        {
            "number": "36",
            "title": "36. Machine saturation at 1.0 pu voltage in pu",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 96
        },
        {
            "number": "37",
            "title": "37. Machine saturation at 1.2 pu voltage in pu",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 97
        },
        {
            "number": "38",
            "title": "38. Percentage regulation",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 98
        },
        {
            "number": "39",
            "title": "39. Short circuit characteristics curves",
            "chapter": null,
            "content": "B. Parameters of Excitation Control System:\nB. Parameters of Excitation Control System:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 99
        },
        {
            "number": "1",
            "title": "1. Type of Excitation",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 100
        },
        {
            "number": "2",
            "title": "2. Maximum Field voltage",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 101
        },
        {
            "number": "3",
            "title": "3. Minimum Field voltage",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 102
        },
        {
            "number": "4",
            "title": "4. Rated Field voltage",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 103
        },
        {
            "number": "5",
            "title": "5. Gain factor",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 104
        },
        {
            "number": "6",
            "title": "6. Feedback strength",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 105
        },
        {
            "number": "7",
            "title": "7. Time constant for control amplifier",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 106
        },
        {
            "number": "8",
            "title": "8. Time constant for Exciter",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 107
        },
        {
            "number": "9",
            "title": "9. Time constant for Feedback",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 108
        },
        {
            "number": "10",
            "title": "10. Output voltage of control amplifier",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 109
        },
        {
            "number": "11",
            "title": "11. Maximum output voltage of control amplifier",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 110
        },
        {
            "number": "12",
            "title": "12. Minimum output voltage of control amplifier",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 111
        },
        {
            "number": "13",
            "title": "13. Details of excitation loop in block diagrams showing transfer functions of individual elements using IEEE symbols along with set values.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 112
        },
        {
            "number": "14",
            "title": "14. Dynamic characteristics of over - excitation limiter",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 113
        },
        {
            "number": "15",
            "title": "15. Dynamic characteristics of under -excitation limiter",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 114
        },
        {
            "number": "16",
            "title": "16. Exciter IEEE model / type no.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 115
        },
        {
            "number": "17",
            "title": "17. Exciter response time",
            "chapter": null,
            "content": "C. Parameters of Governor/ Turbine:\nC. Parameters of Governor/ Turbine:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 116
        },
        {
            "number": "1",
            "title": "1. Governor average gain (MW/Hz)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 117
        },
        {
            "number": "2",
            "title": "2. Speeder motor setting range",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 118
        },
        {
            "number": "3",
            "title": "3. Time constant of steam or fuel governor valve",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 119
        },
        {
            "number": "4",
            "title": "4. Governor valve opening limits",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 120
        },
        {
            "number": "5",
            "title": "5. Governor valve rate limits",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 121
        },
        {
            "number": "6",
            "title": "6. Time constant of turbine (HP, IP, LP)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 122
        },
        {
            "number": "7",
            "title": "7. Governor block diagram showing transfer functions of individual elements using IEEE symbols along with set values.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 123
        },
        {
            "number": "8",
            "title": "8. Type of governor, whether IEEE standard governor used",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 124
        },
        {
            "number": "9",
            "title": "9. Regulation and droop",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 125
        },
        {
            "number": "10",
            "title": "10. Fraction of total power generated HP, IP, LP turbine",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 126
        },
        {
            "number": "11",
            "title": "11. Maximum velocity limit FIP, IP, LP turbine",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 127
        },
        {
            "number": "12",
            "title": "12. Minimum velocity limit HP, IP, LP turbine",
            "chapter": null,
            "content": "D. Operational Parameters:\nD. Operational Parameters:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 128
        },
        {
            "number": "1",
            "title": "1. Min. notice required for synchronising a generating unit from de-synchronisation",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 129
        },
        {
            "number": "2",
            "title": "2. Min. time between synchronising different generating units in a generating station",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 130
        },
        {
            "number": "3",
            "title": "3. The minimum block load requirements on synchronising",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 131
        },
        {
            "number": "4",
            "title": "4. Time required for synchronising a generating unit for the following conditions:",
            "chapter": null,
            "content": "a. Hot\nb. Warm\nc. Cold",
            "footnote": "",
            "is_definition": false,
            "sort_order": 132
        },
        {
            "number": "5",
            "title": "5. Maximum Generating Unit loading rate for the following conditions:",
            "chapter": null,
            "content": "a. Hot\nb. Warm\nc. Cold",
            "footnote": "",
            "is_definition": false,
            "sort_order": 133
        },
        {
            "number": "6",
            "title": "6. Minimum load without oil support (MW)",
            "chapter": null,
            "content": "V. Plant Performance:\nV. Plant Performance:\nDaily Demand Profile (Last Year)\nDaily Demand Profile (Last Year)\nHalf-hourly integrated demand throughout the\n\t\t\t\tday\nHalf-hourly integrated demand throughout the\n\t\t\t\tday\nUnits Generated (Million kWH)\nUnits consumed in Auxiliaries (Million kWH)\nUnits supplied from system to Auxiliary Load\nSeasonal Generation\n2.2 Hydroelectric Stations:\n2.2 Hydroelectric Stations:\nI. General:\nI. General:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 134
        },
        {
            "number": "1",
            "title": "1. Name of generating station:",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 135
        },
        {
            "number": "2",
            "title": "2. No. and capacity of units (MW)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 136
        },
        {
            "number": "3",
            "title": "3. Expected level of generation (MU)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 137
        },
        {
            "number": "4",
            "title": "4. Period of generation (in months) per year",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 138
        },
        {
            "number": "5",
            "title": "5. Whether the plant is based on water released from dam/canal for irrigation purposes",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 139
        },
        {
            "number": "6",
            "title": "6. Rating of all major equipments.",
            "chapter": null,
            "content": "a. Turbine\nb. Generators\nc. Generator Transformers\nd. Auxiliary Transformers",
            "footnote": "",
            "is_definition": false,
            "sort_order": 140
        },
        {
            "number": "7",
            "title": "7. Single line diagram of generating station and switchyard",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 141
        },
        {
            "number": "8",
            "title": "8. Relaying and metering diagram",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 142
        },
        {
            "number": "9",
            "title": "9. Neutral grounding of generator",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 143
        },
        {
            "number": "10",
            "title": "10. Excitation control",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 144
        },
        {
            "number": "11",
            "title": "11. Earthing arrangements with earth resistance values",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 145
        },
        {
            "number": "12",
            "title": "12. Communication- Details of PLCC and other communication equipment installed",
            "chapter": null,
            "content": "II. Protection. - (As applicable to thermal generating stations mentioned above)\nII. Protection.\nIII. Switchyard. - (As applicable to thermal generating stations mentioned above)\nIII. Switchyard.\nIV. Generating Units:\nIV. Generating Units:\nA. Parameters of generating units:\n(As applicable to thermal generating station mentioned above)\nB. Parameters of Excitation Control System:\n(As applicable to thermal generating stations mentioned above)\nC. Parameters of governor/ turbine:\n(As applicable to thermal generating stations mentioned above)\nD. Operational Parameters:\n(a) Minimum notice required for synchronising a generating unit from de-synchronisation\n(b) Minimum time between synchronising different generating units in a generating station\n(c) Minimum block load requirements on synchronising",
            "footnote": "",
            "is_definition": false,
            "sort_order": 146
        },
        {
            "number": "3",
            "title": "3. Planning Data Generation.",
            "chapter": null,
            "content": "3.1 For Thermal Generating Stations, if desired by STU:\nConnection:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 147
        },
        {
            "number": "1",
            "title": "1. Report of studies of parallel operation with Transmission System:",
            "chapter": null,
            "content": "a. Load flow studies\nb. Stability studies\nc. Short Circuit studies",
            "footnote": "",
            "is_definition": false,
            "sort_order": 148
        },
        {
            "number": "2",
            "title": "2. Proposed connection with Transmission system:",
            "chapter": null,
            "content": "a: Voltage\nb. No. of circuits\nc. Connection Point(s) / Interface Point(s)\n3.2 For Hydroelectric Generating Stations, if desired by STU:\n(As applicable to thermal generating stations mentioned above)\nPart - II - Distribution\n1 Standard Planning Data Distribution\nI. General:\nI. General:\n1\nSingle Line Diagram\nLicensee-wise up to 66kV substations.\n2\nConsumer Data\nFurnish category wise number of consumers, their\n\t\t\t\tconnected loads to the best judgement of the Distribution\n\t\t\t\tLicensee\n3\nReference to area offices presently in charge of\n\t\t\t\tthe distribution\nII. Connection:\nII. Connection:\n1.\nConnection Points/ Interface Points:\nFurnish single line diagram showing Connection\n\t\t\t\tPoints/ Interface Points.\n2.\nVoltage of supply at Connection Points/\n\t\t\t\tInterface Points:\n3.\nNames of Grid Substation feeding the Connection\n\t\t\t\tPoints/ Interface Points:\nIII. Lines and Substations:\nIII. Lines and Substations:\n1.\nLine Data:\nFurnish length of line and voltages (EHV level)\n2.\nSubstation Data:\nFurnish transformer details of 220/ 11kV, 132/11\n\t\t\t\tkV, 66/22 kV, 66/ 11 kV substations, capacitor installations\nIV. Loads:\nIV. Loads:\n1.\nLoads drawn at Connection Points/ Interface\n\t\t\t\tPoints:\nIf the Distribution Licensee receive power at a\n\t\t\t\tnumber of connection points in a compact area, which are\n\t\t\t\tinterconnected in a ring, then such a Distribution Licensee shall\n\t\t\t\tforward the overall load drawn for overall Area of Supply, as\n\t\t\t\twell as at each connection point with the variation or tolerance\n\t\t\t\tas mutually discussed and agreed upon with the STU.\n2.\nDetails of loads fed at EHV if any:\nGive name of consumer, voltage of supply,\n\t\t\t\tcontract demand and name of grid substation from which line is\n\t\t\t\tdrawn, length of EHT line from grid substation to the consumer's\n\t\t\t\tpremises.\nV. Demand Data (For Ail Loads 5 MW and Above):\nV. Demand Data (For Ail Loads 5 MW and Above):\n1\nType of Load & Rating in HP or kW:\nState whether furnace loads, rolling mills,\n\t\t\t\ttraction loads, other industrial loads, pumping loads etc.\n2\nRated voltage:\n3\nElectrical loading of equipment:\nState number and size of motors, rating of arc\n\t\t\t\tfurnaces/ induction furnace, types of drive and control\n\t\t\t\tarrangements.\n4\nSensitivity of load to voltage and frequency of\n\t\t\t\tsupply:\n5\nMaximum harmonic content of load:\n6\nAverage and maximum phase unbalance of load:\n7\nNearest substation from which load is to be fed:\n8\nLocation map to scale:\nMap shall show the location of load with\n\t\t\t\treference to lines and sub-stations in the vicinity.\nVI. Load Forecast Data:\nVI. Load Forecast Data:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 149
        },
        {
            "number": "1",
            "title": "1. Peak load for Connection Point/ Interface Point as well as peak load and energy forecast for Area of Supply for each of the succeeding five years.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 150
        },
        {
            "number": "2",
            "title": "2. Details of methodology and assumptions on which forecasts are based.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 151
        },
        {
            "number": "3",
            "title": "3. Details of load 5 MW and above.",
            "chapter": null,
            "content": "a. Name of prospective consumer.\nb. Phasing of load.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 152
        },
        {
            "number": "2",
            "title": "2. Detailed Planning Data (Distribution)",
            "chapter": null,
            "content": "I. General:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 153
        },
        {
            "number": "1",
            "title": "1. Schematic single line diagram of Distribution System (showing distribution lines from Connection Points/ Interface Points with Transmission System 220kV/ 1 IkV, 132/11 kV, 66/22 kV & 66/ 11 kV substations, consumer bus if fed directly from Transmission System)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 154
        },
        {
            "number": "2",
            "title": "2. Numbering and nomenclature of,lines and substations (identified with feeding grid substations of the Transmission System and concerned 220kV/l lkV, 132/ 1 lkV, 66/22 kV & 66/11 kV substation).",
            "chapter": null,
            "content": "II. Connection:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 155
        },
        {
            "number": "1",
            "title": "1. Connection Points/ Interface Points (furnish details of existing arrangement of connection)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 156
        },
        {
            "number": "2",
            "title": "2. Details of metering of Connection Points/ Interface Points.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 157
        },
        {
            "number": "3",
            "title": "3. Detailed Planning Data (Distribution)",
            "chapter": null,
            "content": "I. Connection:\nI. Connection:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 158
        },
        {
            "number": "1",
            "title": "1. Connection Points/ Interface Points as applied for",
            "chapter": null,
            "content": "a. New\nb. Upgrading existing connection",
            "footnote": "",
            "is_definition": false,
            "sort_order": 159
        },
        {
            "number": "2",
            "title": "2. Changes in metering at Connection Points/ Interface Points",
            "chapter": null,
            "content": "II. Loads:\nII. Loads:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 160
        },
        {
            "number": "1",
            "title": "1. Details of major loads of 1 MW and above to be contracted for next three years.",
            "chapter": null,
            "content": "Annexure - C\nAnnexure - C\nPlanning Data Requirement by User from STU/ Transmission Licensee (Clause 4.25, Clause 10.6)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 161
        },
        {
            "number": "1",
            "title": "1. Standard Planning Data (Transmission)",
            "chapter": null,
            "content": "1.\nName of the line: (indicating generating\n\t\t\t\tstations and substations to be connected)\n2.\nVoltage of line (kV):\n3.\nNo. of circuits:\n4.\nRoute length (CKM):\n5.\nConductor sizes:\n6.\nLine parameters (PU on 100 MVA base or ohmic\n\t\t\t\tvalues):\nResistance/KM\nInductive Reactance\n\t\t\t\t/KM\nSuceptance/KM\n7.\nApproximate power flow MW & MVAr:\n8.\nLine Route (Topographic Sheets)\n9.\nPurpose of connection:\nReference to scheme, wheeling to other states\n\t\t\t\tetc.\n10.\nApproximate period of construction:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 162
        },
        {
            "number": "2",
            "title": "2. Detailed System Data (Transmission)",
            "chapter": null,
            "content": "I. General:\nI. General:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 163
        },
        {
            "number": "1",
            "title": "1. Single line diagram of the Transmission System up to 66 kV bus at grid substation:",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 164
        },
        {
            "number": "2",
            "title": "2. Name of substation",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 165
        },
        {
            "number": "3",
            "title": "3. Generating station connected",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 166
        },
        {
            "number": "4",
            "title": "4. Number and length of circuits",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 167
        },
        {
            "number": "5",
            "title": "5. Interconnecting transformers",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 168
        },
        {
            "number": "6",
            "title": "6. Substation bus layouts",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 169
        },
        {
            "number": "7",
            "title": "7. Power transformers",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 170
        },
        {
            "number": "8",
            "title": "8. Reactive compensation equipment",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 171
        },
        {
            "number": "9",
            "title": "9. The details of capacitors installed",
            "chapter": null,
            "content": "a. Additional capacitors to be commissioned along with additional loads\nb. Lightning arresters",
            "footnote": "",
            "is_definition": false,
            "sort_order": 172
        },
        {
            "number": "10",
            "title": "10. Bus and/or line reactors",
            "chapter": null,
            "content": "II. Substation Layout Diagrams Showing:\nII. Substation Layout Diagrams Showing:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 173
        },
        {
            "number": "1",
            "title": "1. Bus bar layouts",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 174
        },
        {
            "number": "2",
            "title": "2. Electrical circuitry, lines, cables, transformers, switchgear etc",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 175
        },
        {
            "number": "3",
            "title": "3. Phasing arrangements",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 176
        },
        {
            "number": "4",
            "title": "4. Earthing arrangements",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 177
        },
        {
            "number": "5",
            "title": "5. Switching facilities and interlocking arrangements",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 178
        },
        {
            "number": "6",
            "title": "6. Operating voltages",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 179
        },
        {
            "number": "7",
            "title": "7. Numbering and nomenclature",
            "chapter": null,
            "content": "a. Transformers\nb. Circuits\nc. Circuit breakers\nd. Isolating switches\nIII. Line Parameters: (For AH Circuits)\nIII. Line Parameters: (For AH Circuits)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 180
        },
        {
            "number": "1",
            "title": "1. Designation of line",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 181
        },
        {
            "number": "2",
            "title": "2. Length of line (KM)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 182
        },
        {
            "number": "3",
            "title": "3. No. of circuits, size and type of conductor, thermal rating",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 183
        },
        {
            "number": "4",
            "title": "4. Per circuit values",
            "chapter": null,
            "content": "a. Operating voltage (kV)\nb. Positive phase sequence reactance - ohms/KM\nc. Positive phase sequence resistance - ohms/KM\nd. Positive phase sequence suceptance - mhos/KM\ne. Zero Phase Sequence Reactance - Ohms/Km\nf. Zero phase sequence resistance - ohms/KM\ng. Zero Phase sequence suceptance - mhos/KM\nIV. Transformer Parameters: (For AH Transformers Substation-wise)\nIV. Transformer Parameters: (For AH Transformers Substation-wise)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 184
        },
        {
            "number": "1",
            "title": "1. Rated MVA",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 185
        },
        {
            "number": "2",
            "title": "2. Voltage ratio",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 186
        },
        {
            "number": "3",
            "title": "3. Vector group",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 187
        },
        {
            "number": "4",
            "title": "4. Positive sequence reactance on rated MVA base (Max., min. & normal)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 188
        },
        {
            "number": "5",
            "title": "5. Positive sequence resistance on rated MVA base (max., min. & Normal)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 189
        },
        {
            "number": "6",
            "title": "6. Zero sequence reactance on rated MVA base",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 190
        },
        {
            "number": "7",
            "title": "7. Tap change range (+% to -%) and steps",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 191
        },
        {
            "number": "8",
            "title": "8. Details of tap changer (OFF/ON)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 192
        },
        {
            "number": "9",
            "title": "9. Neutral grounding transformer/resistor values",
            "chapter": null,
            "content": "10. % Impedance (Max/Min/Normal Tap)\nV. Equipment Details: (For A11 Substations):\nV. Equipment Details: (For A11 Substations):",
            "footnote": "",
            "is_definition": false,
            "sort_order": 193
        },
        {
            "number": "1",
            "title": "1. Circuit breakers",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 194
        },
        {
            "number": "2",
            "title": "2. Isolating switches",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 195
        },
        {
            "number": "3",
            "title": "3. Current transformers",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 196
        },
        {
            "number": "4",
            "title": "4. Potential transformers",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 197
        },
        {
            "number": "5",
            "title": "5. Lightning arresters",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 198
        },
        {
            "number": "6",
            "title": "6. Earthing switches",
            "chapter": null,
            "content": "VI. Relaying and Metering:\nVI. Relaying and Metering:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 199
        },
        {
            "number": "1",
            "title": "1. Relay protection installed for all transformers and feeders along with their settings and level of coordination with other users.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 200
        },
        {
            "number": "2",
            "title": "2. Metering Details",
            "chapter": null,
            "content": "VII. System Studies. - Load flow studies (peak and lean load for maximum hydro and maximum thermal generation)\nVII. System Studies.\nTransient stability studies for 3 phase fault in critical lines, and single pole reclosing for 400 kV lines Dynamic stability studies\nShort circuit studies (3 phase and single phase to earth)\nTransmission and distribution losses in the system.\nVIII. Demand Data: (For All Sub-Stations)\nVIII. Demand Data: (For All Sub-Stations)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 201
        },
        {
            "number": "1",
            "title": "1. Demand Profile (peak and off peak load)",
            "chapter": null,
            "content": "(a) Forecast for next five years\nIX. Reactive Compensation Equipment:\nIX. Reactive Compensation Equipment:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 202
        },
        {
            "number": "1",
            "title": "1. Type of equipment (fixed or variable)",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 203
        },
        {
            "number": "2",
            "title": "2. Capacities and/or inductive rating (voltage and MVAr) or its operating range.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 204
        },
        {
            "number": "3",
            "title": "3. Details of control",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 205
        },
        {
            "number": "4",
            "title": "4. Connection Point/ Interface Point to the system.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 206
        },
        {
            "number": "3",
            "title": "3. Detailed Planning Data (Transmission)",
            "chapter": null,
            "content": "I. Connection:\nI. Connection:",
            "footnote": "",
            "is_definition": false,
            "sort_order": 207
        },
        {
            "number": "1",
            "title": "1. Single Line Diagram showing position of connection",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 208
        },
        {
            "number": "2",
            "title": "2. Substation layout diagram",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 209
        },
        {
            "number": "3",
            "title": "3. New",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 210
        },
        {
            "number": "4",
            "title": "4. Addition and alteration",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 211
        },
        {
            "number": "5",
            "title": "5. Revised system studies with changed parameters",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 212
        },
        {
            "number": "6",
            "title": "6. Connection Point/ Interface Point",
            "chapter": null,
            "content": "a. Voltage\nb. Length of circuit\nc. Circuit parameters\nd. PLCC facilities\ne. Relaying with inter tripping arrangements to inter trip system breaker at Connection Point/ Interface Point to isolate on fault\nf. Metering at Connection Point/ Interface Point.\ng. Other communication facility\nAnnexure-D\nAnnexure-D\nStandards and Conditions for Connectivity to the Grid (Objective: Connection Code)\nSchedule -I\nStandards for Connectivity to the Grid\nStandards for Connectivity to the Grid\nGeneral",
            "footnote": "",
            "is_definition": false,
            "sort_order": 213
        },
        {
            "number": "1",
            "title": "1. Standards and Codes of Practice",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 214
        },
        {
            "number": "1",
            "title": "1. Standards and Codes of Practice",
            "chapter": null,
            "content": "(1) The user shall follow the industry best practices and applicable industry standards in respect of the equipment installation and its operation and maintenance.\n(2) The equipment including overhead lines and cables shall comply with the relevant Indian Standards. British Standard (BS) or International Electrotechnical Commission (IEC) Standard, or American National Standards Institute (ANSI) or any other equivalent international standard:\n(3) The effects of wind, storms, floods, lightening, elevation, temperature extremes, icing, contamination, pollution and earthquakes must be considered in the design and operations of the connected facilities.\n(4) Installation, operation and maintenance of the equipment by user shall conform to the relevant standards specified by the authority under Section 177, and section 73 of the Act, as and when they come into force.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 215
        },
        {
            "number": "2",
            "title": "2. Safety - The user shall comply with the CEA (Measures Relating to Safety and Electric Supply) Regulations, 2010.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 216
        },
        {
            "number": "2",
            "title": "2. Safety",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 217
        },
        {
            "number": "3",
            "title": "3. Substation Grounding - Each transmission substation must have a ground mat solidly connected to all metallic structures and other non-energized metallic equipment. The mat shall limit the ground potential gradients to such voltage and current levels that will not endanger the safety of people or damage equipment which are in, or immediately adjacent to, the station under normal and fault conditions. The ground mat size and type shall be based on local soil conditions and available electrical ",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 218
        },
        {
            "number": "3",
            "title": "3. Substation Grounding",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 219
        },
        {
            "number": "4",
            "title": "4. Metering - Meters shall be provided as specified in the Central Electricity Authority (Installation and Operation of Meters) Regulations, 2006 as amended time to time.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 220
        },
        {
            "number": "4",
            "title": "4. Metering",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 221
        },
        {
            "number": "5",
            "title": "5. Basic Insulation Level and Insulation Coordination - (1) Basic Insulation Level (BIL) of various items of equipment and ratings of surge arresters for generating stations, lines and substations shall be decided on the following order of priority, namely:",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 222
        },
        {
            "number": "5",
            "title": "5. Basic Insulation Level and Insulation Coordination",
            "chapter": null,
            "content": "(a) ensuring safety to public and operating personnel;\n(b) avoiding permanent damage to plant;\n(c) preventing failure of costly equipment;\n(d) minimizing circuit interruptions;\n(e) minimizing interruptions of power supply to consumers;\n(2) Insulation coordination of equipment and lines on both sides of a connection point belonging to the user and the grid shall be accomplished and the coordination shall be done by the GETCO (State Transmission Utility).",
            "footnote": "",
            "is_definition": false,
            "sort_order": 223
        },
        {
            "number": "6",
            "title": "6. Protection system and Coordination - (1) Protection system shall be designed to reliably detect faults on various abnormal conditions and provide means and location to isolate the equipment or system automatically. The protection system must be able to detect a power system faults within the protection zone. The protection system should also detect abnormal operating conditions such as equipment failures or open phase conditions.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 224
        },
        {
            "number": "6",
            "title": "6. Protection system and Coordination",
            "chapter": null,
            "content": "(2) Every element of the power system shall be protected by a standard protection system having the required reliability, selectivity, speed, discrimination and sensitivity. Where failure of protective relay in the user's system has substantial impact on the grid, it shall connect an additional protection as back-up protection, besides the main protection.\n(3) Notwithstanding the protection systems provided in the grid, the user shall provide requisite protections for safeguarding his system from the faults originating in the grid.\n(4) Busbar protection and breaker fail protection or Local Breaker Back-up protection shall be provided wherever stipulated in the regulations.\n(5) Special protection scheme such as under frequency relay for load shedding. Voltage instability, angular instability, generation backing down or islanding schemes may also be required to be provided to avert system disturbances.\n(6) Protection coordination issues shall be finalized by the regional power committee.\n(7) User shall develop protection manuals conforming to various standards for the reference and use of its personnel.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 225
        },
        {
            "number": "7",
            "title": "7. Disturbance Recording and Event Logging Facilities - User and substation connected to the grid at a substation shall provide disturbance recording and event logging facilities. All such equipment shall be provided with time synchronization facility for global common time reference.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 226
        },
        {
            "number": "7",
            "title": "7. Disturbance Recording and Event Logging Facilities",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 227
        },
        {
            "number": "8",
            "title": "8. Schematic Diagrams - User shall prepare single line schematic diagrams in respect of its system facility and make the same available to the GETCO (State Transmission Utility), through which his system is connected and the State Load Despatch Centre.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 228
        },
        {
            "number": "8",
            "title": "8. Schematic Diagrams",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 229
        },
        {
            "number": "9",
            "title": "9. Inspection, Test, Calibration and Maintenance prior to connection - Before connecting, the user shall complete all inspections and tests finalized in consultation with the GETCO (State Transmission Utility) to which his equipment is connected. The user shall make available all drawings, specifications and test records of the project GETCO (State . Transmission Utility) or generating station, as the case may be.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 230
        },
        {
            "number": "9",
            "title": "9. Inspection, Test, Calibration and Maintenance prior to connection",
            "chapter": null,
            "content": "Schedule -II\nGrid Connectivity Standards (applicable to generating units only)\nGrid Connectivity Standards (applicable to generating units only)\n(1) The excitation system for every generating unit:\n(a) shall have state of the art excitation system;\n(b) shall have Automatic Voltage Regulator (AVR). Generators of 100MW rating and above shall have Automatic Voltage Regulator with digital control and two separate channels having independent inputs and automatic changeover;\n(c) The Automatic Voltage Regulator of generator of 100 MW and above shall include power system stabilizer (PSS).\n(2) The short-circuit ratio (SCR) for generators shall be as per IEC-34.\n(3) The generator transformer windings shall have delta connection on low voltage side and star connection on high voltage side. Star point of high voltage side shall be effectively (solidly) earthed, so as to achieve the earth fault factor of 1.4 or less.\n(4) All generating machines irrespective of capacity shall have electronically controlled governing system with state speed/load characteristics to regulate frequency. The governors of thermal generating units shall have a droop of 3 to 6%.\n(5) The project of the user shall not cause voltage and current harmonics on the grid which exceed the limits specified .in Institute of Electrical and Electronics Engineers (IEEE) standard 519.\n(6) Generating units located near load centre, shall be capable of operating at rated output for power factor varying between 0.85 lagging (over-excited) to 0.95 leading (under-excited) and generating units located far from load centres shall be capable of operating at rated output for power factor varying between 0.9 lagging (over-excited) to 0.95 leading (under-excited). The above performance shall also be achieved with voltage variation of +5% of nominal frequency variation of +3% and -5% and combined voltage and frequency variation of + 5%. However, for gas turbines, the above performance shall be achieved for voltage variation of + 5%.\n(7) The coal and lignite based thermal generating units shall be capable of generating up to 105% of Maximum Continuous Rating ( subject to maximum load capability under valve wide open condition ) for short duration to provide the frequency response.\n(8) Every generating unit shall have standard protections to protect the units not only from faults within the units and within the station, but also from faults in transmission lines. For generating units having rated capacity greater than 100 MW, two independent sets of protections acting on two independent sets of trip coils fed from independent Direct Current (DC) supplies shall be provided. The protections shall include but not be limited to the Local Breaker Back-up (LBB) protection.\n(9) Bus bar protection shall be provided at the switchyard of all generating station.\n(10) The station auxiliary power requirement, including voltage and reactive requirements, shall not impose operating restrictions on the grid beyond those specified in the Grid Code or state Grid Code as the case may be.\nMinistry of Power\nMinistry of Power\n(Central Electricity Authority)\n(Central Electricity Authority)\nNotification\nNotification\nNew Delhi, the 21st February, 2007\nNew Delhi, the 21st February, 2007\nNo. 12/X/STD(CONN)/GM/CEA.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 231
        },
        {
            "number": "1",
            "title": "1. Short title and commencement.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 232
        },
        {
            "number": "2",
            "title": "2. Definitions.",
            "chapter": null,
            "content": "(1) \"Act\" means The Electricity Act, 2003 (No. 36 of 2003);\n(2) \"Appropriate Load Despatch Centre\" means the National Load Despatch Centre (NLDC), Regional Load Despatch Centre (RLDC) or State Load Despatch Centre (SLDC) or Area Load Despatch Centre as the case may be;\n(3) \"Area Load Despatch Centre'' means the centre as established by the state for load despatch and control in a particular area of the state;\n(4) \"Appropriate Transmission Utility\" means the Central Transmission Utility or State Transmission Utility as the case may be;\n(5) \"Automatic Generation Control\" (AGC) means capability to regulate the power output of selectable units in response to total power plant output, tie-line power flow, and power system frequency;\n(6) \"Automatic Voltage Regulator\" (AVR) means a continuously acting automatic excitation control system to regulate a generating unit terminal voltage;\n(7) \"British Standards\" (BS) means those standards and specifications approved by the British Standards Institution;\n(8) \"Bulk consumer\" means a consumer who avails supply at voltage of 33 kV or. above;\n(9) \"Earth Fault Factor\" at a location in a three-phase system means the ratio of 'the highest root mean square (r.m.s.) phase-to-earth power frequency voltage on a sound phase during a fault to earth (affecting one or more phases)' to 'the r.m.s. phase-to-earth power frequency voltage which would be obtained at the selected location without the fault';\n(10) \"Earthing\" means connection between conducting parts and general mass of earth by an earthing device;\n(11) \"Energy Management System\" (EMS) means a complete system comprising software for facilitating operation of a power system, maintaining safety, reliability and economy;\n(12) \"Event Logging Facilities\" means a device provided to record the chronological sequence of operations of the relays and other equipment;\n(13) \"Frequency\" means the number of alternating cycles per second [expressed in Hertz (Hz)];\n(14) \"Generating Unit\" means an electrical Generator coupled to a prime mover within a Power Station together with all Plant and Apparatus at that Power Station (up to the Connection Point) which relates exclusively to the operation of that generator;\n(15) \"IEC Standard\" means a standard approved by the International Electro technical Commission;\n(16) \"Indian Standards\" (IS) means standards specified by Bureau of Indian Standards;\n(17) \"Interconnection point\" means a sub-station or switchyard at which point the interconnection is established between the requester and the grid;\n(18) \"Isolator\" means a device for achieving isolation of one part of an electrical system from the rest of the system;\n(19) \"Maximum Continuous Rating\" (MCR) of a generating unit means the maximum continuous output in MW at the generator terminals guaranteed by the manufacturer at rated parameters;\n(20) \"New Unit\" means a generating unit for which the requester is seeking connection to the grid;\n(21) \"Power Factor\" means the cosine of the electrical angle between the voltage and current complexors in an AC electrical circuit;\n(22) \"Power System Stabilizer\" (PSS) means controlling equipment which receives input signals of speed, frequency and power to control the excitation via the voltage regulator for damping power oscillations of a synchronous machine;\n(23) \"Protection System\" means the equipment by which abnormal conditions in the grid are detected and fault clearance, actuating signals or indications are initiated without the intervention by the operator;\n(24) \"Reactive Power\" means in relation to an AC electrical system, the product of root mean square (r.m.s.) voltage, root mean square (r.m.s.) current and the sine of the electrical phase angle between the voltage complexor and current complexor, measured in volt-amperes reactive (VAr);\n(25) \"Requester\" means a person such as a Generating Company including captive generating plant or Transmission Licensee (excluding Central Transmission Utility and State Transmission Utility) or Distribution Licensee or Bulk Consumer, who is seeking connection of his new or expanded electrical plant to the Grid at voltage level 33 kV and above;\n(26) \"SCADA\" means Supervisory Control and Data Acquisition System that acquires data from remote locations over communication links and processes it at centralised control location for monitoring, supervision, control as well as decision support;\n(27) \"Site Common Drawing\" means a drawing prepared for a connection site, which depicts layout of connection site, electrical layout, common protection and control drawings and common services;\n(28) \"Site Responsibility Schedule\" (SRS) means a Schedule for demarcating the ownership, responsibility for control, operation and maintenance of the equipment at the interconnection point;\n(29) \"System Protection Scheme\" means a scheme designed to detect abnormal system conditions and take predetermined, corrective action to preserve system integrity and provide acceptable system performance;\n(30) \"Thermal Generating Unit\" means a generating unit using fossil fuels such as coal, lignite, gaseous and liquid fuel;\n(31) \"Total Harmonic Distortion\" (THD) means a measure of distortion of the voltage or current wave form (which shall ideally be sinusoidal) and is the square root of the sum of squares of all voltage or current harmonics expressed as a percentage of the magnitude of the fundamental;\n(32) \"Transmission System\" means a network of transmission lines and sub-stations;\n(33) \"Under Frequency Relay\" means a relay which operates when the system frequency falls below a pre-set value;\n(34) \"User\" means a person such as a Generating Company including captive generating plant or Transmission Licensee (other than the Central Transmission Utility and State Transmission Utility) or Distribution Licensee or Bulk Consumer, whose electrical plant is connected to the grid at voltage level 33 kV and above; and\n(35) \"Voltage Unbalance\" means the deviation between highest and lowest line voltage divided by Average Line Voltage of the three phases.",
            "footnote": "",
            "is_definition": true,
            "sort_order": 233
        },
        {
            "number": "3",
            "title": "3. Applicability of the Regulations",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 234
        },
        {
            "number": "4",
            "title": "4. Objectives",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 235
        },
        {
            "number": "5",
            "title": "5. Standards",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 236
        },
        {
            "number": "6",
            "title": "6. General Connectivity Conditions",
            "chapter": null,
            "content": "(a) protection coordination and settings of its protective relays accordingly;\n(b) agree to maintain meters and communication system in its jurisdiction in good condition;\n(c) participate in contingency operations such as load shedding, increasing or reducing generation, is landing, black start, providing start-up power and restoration as per the procedure decided by the Appropriate Load Despatch Centre;\n(d) furnish data as required by Appropriate Transmission Utility or Transmission Licensee, Appropriate Load Despatch Centre, Appropriate Regional Power Committee, and any committee constituted by the Authority or appropriate Government for system studies or for facilitating analysis of tripping or disturbance in power system;\n(e) carryout modifications in his equipment with respect to short circuit level, protection coordination and other technical reasons considered necessary due to operational requirements;\n(f) abide by the coordinated outage plan of the state and region in respect of generating units and transmission lines as approved by the Regional Power Committee; and\n(g) cooperate with the Regional Power Committee for tuning of Power System Stabilizer provided in the excitation system of the generating unit.\n(a) Appropriate Transmission Utility in case of connection to Inter-state transmission system or intra state transmission system as the case may be;\n(b) Distribution licensee in case of inter-connection to distribution licensee's system; and\n(c) Transmission licensee and Appropriate Transmission Utility, in case of interconnection to a transmission licensee (tri-partite agreement).",
            "footnote": "",
            "is_definition": false,
            "sort_order": 237
        },
        {
            "number": "7",
            "title": "7. Site Responsibility Schedule",
            "chapter": null,
            "content": "(a) Schedule of electrical apparatus services and supplies;\n(b) Schedule of telecommunications and measurement apparatus; and\n(c) Safety rules applicable to each plant and apparatus.\"\n(a) the ownership of equipment;\n(b) the responsibility for control of equipment;\n(c) the responsibility for maintenance of equipment;\n(d) the responsibility for operation of equipment;\n(e) the manager of the site;\n(f) the responsibility for all matters relating to safety of persons at site; and\n(g) the responsibility for all matters relating to safety of equipment at site.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 238
        },
        {
            "number": "8",
            "title": "8. Access at Connection Site",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 239
        },
        {
            "number": "9",
            "title": "9. Site Common Drawings",
            "chapter": null,
            "content": "Annexure-E\nAnnexure-E\nOperation Planning Data (Clause 6.13, Clause 10.4,Clause 10.5)\nA Outage Planning Data:\nI Demand Estimates. - Estimated aggregate annual sales of energy in million units and peak and lean demand in MW and MVAr in the Area of Supply for the next financial year from 1st April to 31st of March shall be submitted before October 15.\nEstimated aggregate monthly sales of energy in million units and peak and lean demand in MW and MVAr in the Area of Supply for the next month shall be submitted before the 15th of the current month.\nHourly demand estimates for the day ahead shall be submitted by the Distribution Licensee to SLDC at 0900 hours every day.\nII. Estimates of load shedding. - Details of discrete load blocks that can be shed to comply with instructions issued by the SLDC when required, from each Connection Point / Interface Point soon after the connection is made.\nII. Estimates of load shedding.\nIII. Year-ahead outage programme. - (For the period 1st April to 31st March)\nIII. Year-ahead outage programme.\n(a) Generating companies' outage programme. - Information shall be furnished by 15th October each year:\n(i) Identification of generating unit\n(ii) MW which will not be available as a result of outage.\n(iii) Preferred start-dates and start-time or range of start-dates and start-times and period of outage.\n(iv) If outages are required to meet statutory requirements, then the latest date by which outage must be taken.\n(b) WRLDC's year-ahead outage programme. - (Affecting Transmission System)\nInformation shall be furnished as draft annual outage plan by 31st December and as final annual outage plan by 31st January.\n(i) MW which will not be available as a result of outage from imports through external connections, including ISGS/SGS.\n(ii) Start-date, start-time and period of outage\n(c) CPP's year-ahead outage programme. - Information to be furnished by 15th October of each year-\n(i) MW which will not be available as a result of outage\n(ii) Start-date and start-time and period of outage\n(d) Distribution Licensee's 'year ahead' outage programme. - Information shall be furnished by 15th October each year (not pertaining to internal distribution network maintenance, which is not substantially affecting the loading on the Transmission Licensee's lines):\n(i) Load in MW not to be availed from each Connection Point / Interface Point as well as Area of Supply in case of radial feeder and if the distribution system is connected in ring, the Distribution Licensee shall furnish the load in MW not to be availed for his Area of Supply.\n(ii) Period of suspension of drawal with start-date and start-time.\n(e) Advance intimation required for outage for construction of new EHV lines and maintenance due to any unforeseen trouble , but which can be planned and not of extreme nature; shall be given by the Transmission Licensee / Distribution Licensee to SLDC as under.\nLine Voltage\nLine Voltage\nAdvance notice in days\nAdvance notice in days\n66kV\n7\n132kV\n7\n220kV\n10\n400kV\n15\nHVDC (± 500kV)\n15\nB Generation Scheduling Data.\n(a) Status of generating unit AVR in service (Yes/No) of all generating units at 0900 hrs every day\n(b) Status of generating unit speed controls system governor in service (Yes/No) of all generating units at 0900 hrs every day\n(c) Backing down capability with/without oil support (MW) of all thermal generating units at 0900 hrs every day\n(d) Hydro reservoir level & restrictions for all generating units at 0900 hrs every day\nC. Capability Data:\n•   Generators shall submit to SLDC up-to-date capability curves for all generating units on receipt of request from SLDC\n•   CPPs shall submit to SLDC net return capability that shall be available for export/import from Transmission System on receipt of request from SLDC\nD. Response to Frequency Change:\n•   Primary response in MW at different levels of loads ranging from minimum generation to registered capacity for frequency changes resulting in fully opening of governor valve\n•   Secondary response in MW to frequency changes\nE. Monitoring of Generation:\n•   Logged readings of generators to SLDC whenever required\n•   Detailed report of generating unit tripping on monthly basis\nF. Essential and Non-essential Load Data.\nG. Protection Data:\n•   Generators/CPPs shall submit details of protection requirement and schemes installed by them as per detailed planning data.\n•   The Transmission Licensee shall submit details of protection equipment and schemes installed by them.\n•   Detailed system data required for relaying and metering of transmission lines and substations in relation to connection with any user, as per detailed planning data.\nH. Metering Data:\n•   Generators/CPPs shall submit details of metering equipment and schemes installed by them\n•   Detailed planning data\n•   STU/ Transmission Licensee shall submit details of metering equipment and schemes instilled by them\nAnnexure F\nAnnexure F\nMetering and Protection Standards (Clause No. 6.46, 6.68)\nI. Introduction. - This standard provides guidelines for the following:\nI. Introduction.\n(a) Minimum requirement of metering for commercial and operational purposes to be provided by the user at Connection Points/ Interface Points including _ generating stations, switching stations, substations and also cross boundary circuits.\n(b) Minimum requirement of protection to be provided to safeguard the system from faults which may occur.\nII. Metering Requirements. - Generating Station Operational Metering:\nII. Metering Requirements.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 240
        },
        {
            "number": "1",
            "title": "1. The generating companies shall install operational metering to the licensees' specifications, so as to provide operational information for both, real time and recording purposes to SLDC in relation to each generating unit, at each generating station, in respect of the following:",
            "chapter": null,
            "content": "(a) Bus voltage\n(b) Frequency\n(c) MW\n(d) MVAr\n(e) Any other data agreed to between the licensee and the generating company",
            "footnote": "",
            "is_definition": false,
            "sort_order": 241
        },
        {
            "number": "2",
            "title": "2. All the instrument transformers used in conjunction with the operational metering shall be of accuracy class 0.2, except where already existing CT/PT; which are of 0.5 class, which may continue to be used. These shall be of suitable rating to meet the burden of lead wires and meters and shall conform to the relevant IEC or IS specifications.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 242
        },
        {
            "number": "3",
            "title": "3. All the meters shall be calibrated to achieve the overall accuracy of Operational Metering in accordance with the limits agreed to between the Transmission Licensee/Distribution Licensee and the generating company. Records of calibration shall be maintained for reference and shall be made available to the licensee, upon request. Joint site testing shall be carried out at least once in six months.",
            "chapter": null,
            "content": "III. Transmission System Operational Metering. - The Transmission Licensee shall install operational metering for both, real time and recording purposes at each substation as follows:\nIII. Transmission System Operational Metering.\n(a) For station busbars:\n(i) bus voltage\n(ii) frequency\n(b) For outgoing/incoming lines, power transformers, auxiliary transformers and compensating devices:\n(i) MW\n(ii) MVAr\n(iii) Power Factor\n(iv) Current\nIV. Supervisory Control and Data Acquisition (SCADA)\nIV. Supervisory Control and Data Acquisition (SCADA)",
            "footnote": "",
            "is_definition": false,
            "sort_order": 243
        },
        {
            "number": "1",
            "title": "1. The Transmission Licensee shall install and make operative an Operational Metering Data Collection System under SCADA for storage, display and processing of operational metering data. All users shall make available outputs of their respective operational meters to the SCADA interface equipment.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 244
        },
        {
            "number": "2",
            "title": "2. The data collection, storage and display centre shall be the State Load Despatch Centre (SLDC).",
            "chapter": null,
            "content": "V. Tariff Metering\nV. Tariff Metering",
            "footnote": "",
            "is_definition": false,
            "sort_order": 245
        },
        {
            "number": "1",
            "title": "1. The Generating Companies, CPP, Transmission Licensees, Distribution Licensees and EHV consumers who intend to use open access provisions would need to install the meters suitable for Availability Based Tariff (ABT) at interutility exchange points, which would record the parameters as mentioned under clause V.9.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 246
        },
        {
            "number": "2",
            "title": "2. The auxiliary transformers in the generating stations shall be provided with the following meters:",
            "chapter": null,
            "content": "(a) MW\n(b) Current\n(c) Voltage\n(d) Active\n(e) Energy",
            "footnote": "",
            "is_definition": false,
            "sort_order": 247
        },
        {
            "number": "3",
            "title": "3. Each metering point associated with determination of energy exported or imported, between the generating companies, Transmission Licensees and Distribution Licensees shall be provided with both, main and check meters on separate core of CT/EMPT/CVT. The minimum standard of accuracy for these meters shall be accuracy class 0.2s. If the present metering system needs upgradation to class 0.2s, it shall be completed within six months from the effective date of this code.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 248
        },
        {
            "number": "4",
            "title": "4. All the instrument transformers used in conjunction with commercial (tariff) metering shall also be of accuracy class 0.2s, except where already existing CT/EMPT/CVT/ which are of 0.5 class, shall be upgraded to class 0.2s within two years from the effective date of this code. These shall conform to the relevant IEC or IS specifications. The rating shall take into account the burdens imposed by lead wires and metering.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 249
        },
        {
            "number": "5",
            "title": "5. Accuracy class: All interface meters and meters for energy accounting and audit shall be of 0.2S class of accuracy. Consumer meters shall have the following characteristics:",
            "chapter": null,
            "content": "(a) For the consumers connected at above 33 kV voltage level should be of 0.2S class of accuracy,\n(b) Consumers connected at above 650 volts and up to 33 kV shall be of 0.5S or better accuracy class,\n(c) Consumers connected at 650 volts or below shall be of accuracy class 1 or better,\n(d) The accuracy class of current transformers (CTs) and voltage transformers (VTs) shall not be inferior to that of associated meters. However, till the VTs of 0.2S class of accuracy is available, 0.2 accuracy class may be installed. The existing CTs and VTs not complying with these regulations shall be replaced by new CTs and VTs, if found defective, non-functional or as per the directions of the Commission.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 250
        },
        {
            "number": "6",
            "title": "6. Data shall be collected from both, the main and check metering schemes.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 251
        },
        {
            "number": "7",
            "title": "7. Voltage failure relays shall be provided to initiate alarm on loss of one or more phases of the voltage supply to the meter.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 252
        },
        {
            "number": "8",
            "title": "8. All the meters shall be tested and calibrated at least once in every five years, using standard meters for this purpose. The standard meters shall be calibrated and sealed at a government- authorized meter testing house/laboratory once a year. Records of testing and calibration of substandard meters shall be maintained by the Transmission Licensee according to the guidelines provided in the relevant IEC/IS specifications. Records of these calibrations and tests shall be maintained for referen",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 253
        },
        {
            "number": "9",
            "title": "9. In case of Inter State Transmission Lines / Intra-State Transmission lines, meters suitable for Availability Based Tariff shall be provided having the following parameters:",
            "chapter": null,
            "content": "(a) Net Active Energy import/ export for each 15 minute time block of the day\n(b) Net Reactive Energy import/ export for the day above 103% of voltage\n(c) Net Reactive Energy export/ import when voltage is below 97%\n(d) Cumulative active energy export/ import.\n(e) Average frequency for each 15 minute time block of the day\n(f) Provision of storage of data in non-volatile memory for at least 10 days",
            "footnote": "",
            "is_definition": false,
            "sort_order": 254
        },
        {
            "number": "10",
            "title": "10. The Generating Companies, Transmission Licensees and Distribution Licensees shall formulate a procedure, covering the summation, collection and processing of tariff meter readings at various connection sites in their areas. Whenever necessary, these procedures can be revised.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 255
        },
        {
            "number": "11",
            "title": "11. The ownership, responsibility of maintenance and testing of these meters shall be as mutually agreed, between the users and the licensees.",
            "chapter": null,
            "content": "VI. Protection Requirements. - General Principles\nVI. Protection Requirements.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 256
        },
        {
            "number": "1",
            "title": "1. No item of electrical equipment shall be allowed to remain connected to the system, unless it is covered by the appropriate protection aimed at reliability, selectivity, speed and sensitivity. The guidelines mentioned in the manual on protection of generators, generator transformers, and 220 kV and 400 kV networks vide publication no 274 of C.B.I.P shall be kept in view. All the generating companies and Distribution Licensees shall cooperate with the Transmission Licensee(s) to ensure correct",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 257
        },
        {
            "number": "2",
            "title": "2. Protection settings shall not be altered, or protection bypassed and/or disconnected without consultation and agreement of all affected users. In case the protection has been bypassed and/or disconnected by agreement due to any cause, the same should be rectified and protection restored to normal conditions, as quickly as possible. If agreement has not been reached, the electrical equipment shall be isolated forthwith.",
            "chapter": null,
            "content": "VII. Protection Coordination\nVII. Protection Coordination",
            "footnote": "",
            "is_definition": false,
            "sort_order": 258
        },
        {
            "number": "1",
            "title": "1. The settings of protective relays starting from the generating unit up to the remote end of 66 kV / 33 kV and 11 kV lines shall be such that only the faulty section is isolated under all circumstances. The Transmission Licensee shall notify the initial settings and any subsequent changes to the users from time to time. Routine checks on the performance of the protective relays shall be conducted and any malfunction shall be noted and corrected as soon as possible. The Transmission Licensee sh",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 259
        },
        {
            "number": "2",
            "title": "2. The Transmission Licensee shall be responsible for arranging periodical meetings between the generating companies and Distribution Licensees to discuss coordination of protection. The Transmission Licensee shall investigate any malfunction of protection or other unsatisfactory protection issues. The concerned licensees shall take prompt action to correct any protection malfunction or issue as discussed and agreed to in these periodical meetings.",
            "chapter": null,
            "content": "VIII. Fault Clearance Time\nVIII. Fault Clearance Time",
            "footnote": "",
            "is_definition": false,
            "sort_order": 260
        },
        {
            "number": "1",
            "title": "1. From stability considerations, the maximum Fault Clearance Time for faults on any user's system directly connected to the Transmission System, or any faults on the Transmission System itself, shall be as follows:",
            "chapter": null,
            "content": "Voltage Class\nVoltage Class\nTarget Clearance Time\nTarget Clearance Time\n400kV\n100 milliseconds\n220kV\n120 milliseconds\n132kV\n160 milliseconds\n66kV\n300 milliseconds",
            "footnote": "",
            "is_definition": false,
            "sort_order": 261
        },
        {
            "number": "2",
            "title": "2. Less Fault Clearance Time than the above is preferable.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 262
        },
        {
            "number": "3",
            "title": "3. Lower Fault Clearance Times for faults on a user's system may be agreed to, but only if, in the opinion of the Transmission Licensee, system conditions allow the same. At the generating stations, line faults should be cleared at the generating station end, within the critical time, to keep the generators in synchronism.",
            "chapter": null,
            "content": "IX. Generator Requirements. - All generating units and all associated electrical equipment of the generating company connected to the Transmission System shall be protected by adequate protection, as per CBIP manual vide publication 274, so that the Transmission System does not suffer due to any disturbances originating at the generating unit.\nIX. Generator Requirements.\nX. Transmission Line Requirements. - Every EHT line taking off from a generating station or a substation or a switching station shall necessarily have distance protection along with other protection as follows:\nX. Transmission Line Requirements.\n(a) 400 kV lines. - These lines shall have two main distance protections; viz. Main I and Main II with permissive inter trip for remote earth fault. Three zone static/numerical non- switched distance protection with permissive inter trip for accelerated tripping at remote end in case of zone 2 fault as Main I protection shall be provided. Main II protection shall be similar fast protection using direction comparison or phase comparison carrier relay scheme. In addition to the above, single pole tripping and single shot single pole auto reclosing after an adjustable dead time shall be provided. In addition to the above, back- up protection with OCR and EFR shall be provided.\n(b) 220 kV lines. - Three zone static/numerical non-switched distance protection, with permissible inter-trip for end zone fault as main protection in case of zone 2 fault shall be provided. The back-up shall be three-phase directional over current relay and earth fault relay protection. Three pole tripping and Single Shot Three Pole Auto-reclosing with adjustable dead time shall be provided for the stability of the power system. However, for short 220 kV lines directional comparison or phase comparison carrier protection as Main II can be provided. In addition to the above back-up protection with directional OCR (Over Current Relay) and directional EFR (Earth Fault Relay) shall be provided.\n(c) 132 kV lines. - Three zone static/numerical switched protection with permissible inter trip for accelerated tripping at the remote end in case of zone 2 protection shall be provided as main protection. The back-up will be directional three-phase over current and earth fault protection.\n(d) Busbar Protection. - Adequate busbar protection for the station busbar sections in all 400 kV and 220 kV class substations shall be provided.\n(e) Local Breaker Backup Protection (LBB). - In the event of any circuit breaker failing to trip on receipt of trip command from protective relays, all circuit breakers connected to the bus section to which the faulty circuit breaker is connected are required to be tripped with minimum possible delay through LBB protection. This protection also provides coverage for faults between the circuit breaker and the current transformer, which are not covered by other protections. All 220 kV and 400 kV circuits shall have Local Breaker Back-up Protection.\n(f) 400 kV class Power Transformers. - These shall be provided with differential protection, restricted earth fault protection, Bucholtz protection, and winding temperature protection along with back-up directional HV & LV IDMT over current protection.\n(g) 220 kV, 132 kV and 66 kV class power transformers. - These shall have differential protection, restricted earth fault protection, Bucholtz protection, and winding/oil temperature protection. They shall also have directional over current as back-up protection with an instantaneous element. In addition to the above, Over Fluxing Relays, pressure relief valves/diaphragms shall be provided for all the power transformers. Appropriate fire protection for all the power transformers as per CBIP specifications and tariff advisory committee recommendations shall be provided. Over Fluxing Relays shall be provided on transformers having rating more than 100 MVA.\n(h) Distribution System. - For smaller transformers of HV class on the distribution system, differential protection shall be provided for 8 MVA capacity and above, along with back- up time lag over current and earth fault protection with directional feature for parallel operation. Transformers of 1.6 MVA capacity and above, but less than 8 MVA shall be protected by time lag over current, earth fault and instantaneous restricted earth fault relays. In addition, all transformers of 1.6 MVA and above shall be provided with gas operated relays, winding and oil temperature protection.\n(i) Distribution Lines. - All the 33 kV, 22 kV and 11 kV lines at Connection Points/ Interface Points shall be provided with a minimum of over current and earth fault relays as follows:\n(j) Plain Radial Feeders. - Directional over current and earth fault relays with suitable settings to obtain discrimination between adjacent relay settings.\n(k) Parallel/Ring Feeders. - Directional time lag over current and earth fault relay.\n(1) Inadvertent Flow. - When two systems are operating in parallel with floating tie-line, it may not be possible to have tie-line absolutely floating because of dynamics of network parameters and there will be a flow of energy from one system to another system. Such inadvertent flow shall be accounted for the purpose of commercial billing.\nAnnexure G\nAnnexure G\nRequisition for Line Clear Permit (Clause No. 7.21)\n1 Mr/Ms....................... request Line Clear Permit on the following HT/EHT line/equipment\nHV/EHV Apparatus/Line Identification:\nDetails of works to be carried out:\nEstimated time required for completion:\n(Requesting Safety Coordinator)\n(In-charge of crew)\nDesignation......................\n........................\nDate.............................\n........................\n(a) Line Clear Permit issued : Yes/No\n(b) Number and date of issue (Code No.):\n(c) Time of issue:\n(d) Date & time of return:\n(e) Remarks: see check list LCP - H\n(Authorised Site Incharge)\nConditions:\n(a) This permit is valid only for working in the feeder/equipment mentioned herein and not in any other feeder/equipment.\n(b) Only authorised persons are allowed to work on feeders/equipments for which the permit has been issued.\n(c) Works as per requisition only should be carried out.\n(d) Before touching any part of the feeder/equipment, the same should be earthed at two points on either side through standard discharge rods connected with good earth. Temporary earthing may only be removed after completion of all works and after all the men have come down from the feeder/equipment.\n(e) Work should be so planned that the Line Clear is returned before or at the time indicated. If unavoidable delay is anticipated, advance information should be given to the location from where the Line Clear is issued.\n(f) Before return of the Line Clear, it should be ensured that all the men, materials, tools/tackles etc. on line have returned and reported that all temporary returned and reported and all temporary earths removed. There should also be a check on the material, tools and plant issued for the work to ensure that nothing is left behind on the line or equipment.\n(g) Only authorised persons should return Line Clear.\n(h) In case the Line Clear cannot be returned in person, the same may be returned to the Line Clear Issuing Authority over telephone by naming the code words assigned and the telephone number which is used for naming the code words assigned. In case two or more different code words are issued to the two or more persons in whose favour the permit is given, those persons must jointly return the Line Clear by naming their own code words. The Line Clear Return will not be deemed to be accepted unless returned by all these persons.\n(i) The Line Clear issuing authority should go over the checklist of Line Clear Return before accepting it.\n(j) If Line Clear is returned over telephone, the Line Clear return form duly filled and signed should be sent to the Line Clear issuing authority by post immediately for record.\n(k) Control person should keep all the required data of LCP issued & LCR received. He should monitor and keep specific note in log sheet when more than one LCP are issued on same line/ equip/bay along with code words.\nAnnexure H\nAnnexure H\nCheck list for Line Clear Permit and Line Clear Permit (Clause No.7.21)\nCheck List of the Line Clear Permit:\n(a) Name of location for which line clear is issued\n(b) Reference and authority requisitioning Line Clear: (Indicate original LCP-G number including suffix and prefix)\n(c) Identity of HV Apparatus\n(d) Sources from which the line/equipment is charged\n(e) Number/name of circuit breaker/isolating switch open at each of above sources\n(f) Whether confirmed that the line is disconnected at both ends\n(g) Whether line is earthed at both ends\n(h) Whether circuit breaker truck removed in case of indoor switchgear controlling the feeder/equipment for which line clear is given\n(i) Whether fuses of control supply voltage of the circuit breaker/isolating switches controlling the feeder/equipment for which line clear is given are removed and kept in safe custody\n(j) Time of issue of Line Clear Permit and LCP-G No.\n(k) Name of requesting line clear permit on whom LCP-G is issued\n(l) Approximate time for returning LCP-G as ascertained from the requesting coordinator\n(authorised station shift incharge)\nAnnexure I\nAnnexure I\n(a) HV/EHV Apparatus/Line Identification:\n(b) Safety precaution no longer required:\n(c) Isolation [state locations and each point of isolation indicating means by which isolation was achieved]\n(d) Earthing [state location at which earthing was established and identify each point of earthing\n(e) Details of work done\nCheck list to be ticked off:\n(a) Whether all men withdrawn: Yes/No\n(b) Whether all temporary earth removed: Yes/No\n(c) Whether materials, tools and plant used in the work have been checked: Yes/No\n(d) Code Number (If used when Line Clear is returned over phone)................................\nAnnexure J\nAnnexure J\nRegulatory Requirements of Special Energy Meters (Clause No 11.16)\n(i) Average frequency for each successive 15-minute block, as a two digit code (00 to 99 for frequency from 49.0 to 51.0Hz)\n(ii) Net Wh transmittal during each successive 15-minute block, up to second decimal, with plus/minus sign\n(iii) Cumulative Wh transmittal at each midnight, in six digits including one decimal\n(iv) Cumulative VArh transmittal for voltage high condition, at each midnight, in six digits including one decimal\n(v) Cumulative VArh transmittal for voltage low condition, at each midnight, in six digits including one decimal\n(vi) Date and time blocks of failure of VT supply on any phase, as a star (*) mark\n(i) Unique identification number of the meter\n(ii) Date\n(iii) Time\n(iv) Cumulative Wh register reading\n(v) Average frequency of the previous 15-minute block\n(vi) Net Wh transmittal in the previous 15-minute block, with +/- sign\n(vii) Average percentage voltage (viii) Reactive power with +/- sign\n(ix) Voltage-high VArh register reading\n(x) Voltage-low VArh register reading\nAnnexure K\nAnnexure K\nPayment for Reactive Energy Exchanges on Lines Owned By Individual Entities (Clause No.11.55)\n(i) Net VArh received from Entity A while voltage is below 97%\n(ii) Net VArh supplied to Entity A while voltage is above 103%\nNote. - Net VArh and net payment may be positive or negative\nNote.\n(i) Entity-B pays to Entity-A for XI or X3, whichever is smaller in magnitude, and\n(ii) Entity-A pays to Entity-B for X2 or X4, whichever is smaller in magnitude.\nNote.\nNote.",
            "footnote": "",
            "is_definition": false,
            "sort_order": 263
        },
        {
            "number": "1",
            "title": "1. Net VArh and net payment may be positive or negative.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 264
        },
        {
            "number": "2",
            "title": "2. In case XI is positive and X3 is negative, or vice-versa, there would be no payment under (i) above.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 265
        },
        {
            "number": "3",
            "title": "3. In case X2 is positive and X4 is negative, or vice-versa, there would be no payment under (ii) above.",
            "chapter": null,
            "content": "",
            "footnote": "",
            "is_definition": false,
            "sort_order": 266
        }
    ],
    "metadata": {
        "Act ID": "Last Updated 8th November, 2019 [guj293]",
        "Act Number": "",
        "Enactment Date": "",
        "Act Year": "2013",
        "Short Title": "Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013",
        "Type": "STATE",
        "Location": "Gujarat"
    },
    "updated_at": "2026-09-29 21:55:19"
}

Gujarat Electricity Regulatory Commission (Gujarat Electricity Grid Code) Regulations, 2013

Sections

1. Short title, extent and commencement.

1. Introduction

1. Introduction. - This section outlines the broad features of the Grid Code.

2. Definitions. - The various terms used in the Grid Code are defined under this section.

3. Management of Grid Code and role of various organizations. - The Grid Code is a live document and has to be periodically reviewed by a competent panel, as and when required, in the light of experience gained. This section formulates the procedures for the same.

4. System planning code. - This , section specifies the technical and design criteria and the procedures to be applied by the State Transmission Utility and other users for planning and development of the power system.

5. Connectivity Conditions. - This section specifies the technical criteria and standards to be complied with by STU, transmission licensees, the generating companies, distribution licensees and other users connected or seeking connection to the transmission system.

6. System Operation Code. - 6.1 Operation Planning and Security. - This section specifies the process by which STU has to carry out the planning of the intra-state transmission system, including interface coordination with the users, for a satisfactory grid operation and system integrity.

6. System Operation Code.

8. Communication and Data Acquisition. - This section specifies the minimum requirements of communication and data acquisition facilities to be provided by each user at connection points/ interface points and cross-boundary circuits.

9. Operational Event and Incident/Accident Reporting. - This section specifies the details of minimum requirement for the exchange of information relating to operations and/or events in the total system, including the Western Grid, which may have an operational effect.

2. Definitions.

3. Management of Grid Code and Role of Various Organizations.

1. Reports on the outcome of such review

2. Any proposed revision to the Grid Code as STU reasonably thinks necessary for achievement of the objectives referred to in the relevant paragraphs of the Transmission Licence

3. All written representations and obj ections submitted by the users at the time of review

1. Section 39 of the Electricity Act, 2003, outlines that the functions of the State Transmission Utility (STU) shall be:

2. Until a government company or any authority or corporation is notified by the State Government, the State Transmission Utility shall operate the State Load Despatch Centre as per Section 31 of the Act.

4. System Planning Code.

1. As a general rule, the Intra State Transmission System shall be capable of withstanding and be secured against the following contingency outages

1. The following minimum safety working clearance shall be maintained for the bare conductors or live parts of any apparatus in outdoor substation, excluding overhead lines of HV and EHV installation. (As per CEA notification of 20th Sept, 2010, clause no. 44(2)-(iii)):

2. Clearance above ground of the lowest conductor (as per CEA notification of 20th Sept, 2010, clause no.58):

3. Clearance from building of high and extra-high voltage lines (as per CEA notification of 20th Sept, 2010, clause no. 61)

5. Connection Code.

2. Wind generating stations and solar generating stations shall have fault ride through capability of not less than 300 milli-seconds so that grid is not destabilized due to sudden outage of generation in the event of a grid disturbance.

6. System Operation Code

7. Safety.

8. Communication and Data Acquisition.

9. Operational Event and Incident/Accident Reporting.

10. Data Registration.

11. Schedule and Despatch Code.

1. Introduction.

2. Transmission Planning

3. System Studies

4. System Data

5. Generation

6. Planning Criteria

7. Security Standards

8. Substation Planning Criteria

9. Reactive Compensation

1. Standard Planning Data (Generation)

2. Detailed Planning Data (Generation)

1. Name of generating station

2. No. and capacity of generating units (MW)

3. Single line diagram of generating station and switchyard

4. Relaying and metering diagram

5. Neutral grounding of generating units

6. Excitation control

7. Earthing arrangements with earth resistance values

8. Communication- details of PLCC and other communication equipment installed

1. In relation to Interconnecting Transformers between EHV / HV Transmission System and the Generator Transformer Voltage System:

2. In relation to switchgear including circuit breakers, isolators on all circuits connected to the points of connection:

3. Lightning arresters, technical data

4. Communication- Details of PLCC and other communication equipment installed at Connection Point(s)/ Interface Point(s).

5. Basic insulation level (kV)

1. Rated terminal voltage (kV)

2. Rated MVA

3. Rated MW

4. Inertia constant H (MW Sec./MVA) of generator

5. Short circuit ratio

6. Direct axis synchronous reactance (% on MVA) (Both unsaturated and saturated)

7. Direct axis transient reactance (% on MVA) (Both unsaturated and saturated)

8. Direct axis sub-transient reactance (% on MVA) (Both unsaturated and saturated)

9. Quadrature axis synchronous reactance (% on MVA) (Both unsaturated and saturated)

10. Quadrature axis transient reactance (% on MVA) (Both unsaturated and saturated)

11. Quadrature axis sub-transient reactance (% on MVA) (Both unsaturated and saturated)

12. Direct axis transient open circuit time constant (Sec) T' do

13. Direct axis sub-transient open circuit time constant (Sec) Tdo

14. Quadrature axis transient open circuit time constant (Sec) T' qo

15. Quadrature axis sub-transient open circuit time constant (Sec) Tqo

16. Stator resistance (Ohm)

17. Stator leakage reactance (Ohm) Ta

18. Stator time constant (Sec)

19. Rated field current (A)

20. Open circuit saturation characteristic for various terminal voltages giving the exciting current to achieve the same.

21. Generator Capability Curve

22. Rated stator current (A)

23. Phase connection